U.S. patent application number 14/050325 was filed with the patent office on 2014-04-24 for system, method, and apparatus for settlement for participation in an electric power grid.
The applicant listed for this patent is Joseph W. Forbes, Jr.. Invention is credited to Joseph W. Forbes, Jr..
Application Number | 20140114849 14/050325 |
Document ID | / |
Family ID | 49518134 |
Filed Date | 2014-04-24 |
United States Patent
Application |
20140114849 |
Kind Code |
A1 |
Forbes, Jr.; Joseph W. |
April 24, 2014 |
SYSTEM, METHOD, AND APPARATUS FOR SETTLEMENT FOR PARTICIPATION IN
AN ELECTRIC POWER GRID
Abstract
Systems, methods, and apparatus embodiments for electric power
grid and network registration and management of physical and
financial settlement for participation of active grid elements in
supply and/or curtailment of power. Settlement is provided for grid
elements that participate in the electric power grid following
initial registration of each grid element with the system,
preferably through network-based communication between the grid
elements and a coordinator, either in coordination with or outside
of an IP-based communications network router. A multiplicity of
active grid elements function in the grid for supply capacity,
supply and/or load curtailment as supply or capacity, and are
compensated through settlement for their functional participation
in the electric power grid. Also, messaging related to settlement
is managed through a network by a Coordinator using IP messaging
for communication with the grid elements, with the energy
management system (EMS), and with the utilities, market
participants, and/or grid operators.
Inventors: |
Forbes, Jr.; Joseph W.;
(Raleigh, NC) |
|
Applicant: |
Name |
City |
State |
Country |
Type |
Forbes, Jr.; Joseph W. |
Raleigh |
NC |
US |
|
|
Family ID: |
49518134 |
Appl. No.: |
14/050325 |
Filed: |
October 9, 2013 |
Related U.S. Patent Documents
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Application
Number |
Filing Date |
Patent Number |
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13746703 |
Jan 22, 2013 |
8583520 |
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14050325 |
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13659564 |
Oct 24, 2012 |
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13746703 |
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Current U.S.
Class: |
705/40 |
Current CPC
Class: |
G05D 3/12 20130101; Y04S
50/12 20130101; Y04S 10/126 20130101; Y04S 50/10 20130101; H02J
13/00034 20200101; G06Q 10/00 20130101; Y02T 10/70 20130101; H02J
13/00028 20200101; G06Q 40/04 20130101; G06Q 30/0206 20130101; Y04S
50/14 20130101; G05D 17/00 20130101; Y02T 90/14 20130101; G06Q
40/00 20130101; Y02T 90/16 20130101; G06Q 20/102 20130101; G06Q
50/06 20130101; Y02P 90/845 20151101; Y04S 40/128 20130101; Y02P
80/10 20151101; G07F 15/008 20130101; B60L 53/305 20190201; B60L
53/68 20190201; G06Q 30/0283 20130101; Y04S 30/14 20130101; B60L
53/64 20190201; Y02T 10/7072 20130101; B60L 53/63 20190201; H04L
69/325 20130101; H02J 2203/20 20200101; H02J 13/0086 20130101; Y02T
90/167 20130101; H02J 3/008 20130101; Y02T 90/12 20130101; B60L
55/00 20190201; G06Q 20/145 20130101; G06Q 30/04 20130101; H04L
69/22 20130101; Y02E 60/00 20130101; G06Q 20/14 20130101 |
Class at
Publication: |
705/40 |
International
Class: |
G06Q 50/06 20060101
G06Q050/06; G06Q 20/10 20060101 G06Q020/10 |
Claims
1. A system for market-based settlement of transactions within an
electric power grid network comprising: a settlement processor for
market-based financial settlements comprising a server and/or a
processor operatively coupled with a memory, and a database
constructed and configured for electrical connection and IP-based
communication via a network with at least one active grid element;
wherein each active grid element is registered to participate
within the electric power grid; and wherein the settlement
processor provides automated messaging used for a market-based
financial settlement based upon revenue grade metrology data and a
kilowatt packet (KWP) unit; wherein each KWP unit provides a
quantifying market rate for monetization for any unit of kilowatts
with respect to time.
2. The system of claim 1, wherein each KWP unit further comprises
measured data transformed into market settlement data used for
financial settlement for an electric power load, an electric power
supply, and/or transmission distribution service provider (TDSP)
corresponding to at least one of the active grid element(s)
participation in the electric power grid for the corresponding
electric power load, curtailment, the electric power supply, and/or
TDSP.
3. The system of claim 1, wherein the settlement processor operates
to provide an automatic and/or autonomous financial settlement for
each of the active grid elements based upon their participation
within the electric power grid for providing the electric power
supply, for consuming the electric power load, and/or for providing
a curtailment of the electric power load that is functionally
equivalent to the electric power supply.
4. The system of claim 1, wherein the settlement processor provides
messaging used for the market-based financial settlement further
including a power supply value (PSV) unit, and/or a power trading
block (PTB) unit, wherein the PSV unit is a systematic unit for
addressing power curtailment or power supply for providing grid
stability, reliability, and frequency, and wherein PTB unit is a
standard unit that provides for blocks of energy to be introduced,
aggregated, and settled for a market-based financial
settlement.
5. The system of claim 1, wherein the participation of the grid
element is communicated to the server via an IP-based message over
the network.
6. The system of claim 1, wherein the participation of the grid
element is communicated to the coordinator via the network in
real-time or in a predetermined timeframe.
7. The system of claim 1, further including a multiplicity of grid
elements that aggregate and/or integrate through a master grid
element and/or a virtual grid element that represents the
participation of the multiplicity of grid elements as operationally
equivalent to a single grid element with an aggregated KWP unit
representing the participation of the multiplicity of grid
elements.
8. The system of claim 7, wherein each of the multiplicity of grid
elements, upon aggregation or integrations, transform into sub-grid
elements.
9. The system of claim 1, wherein a unique market-based financial
settlement message is generated for each sub-grid element that
further includes coordination with at least one virtual ID and/or
smart meter.
10. The system of claim 1, wherein each grid element further
includes an assigned identifier including an IP address that is
unique to that grid element for the market-based financial
settlement.
11. The system of claim 1, wherein the at least one grid element is
an electrical device that consumes power from the electric power
grid, provides power to the electric power grid, and/or measures
power consumed or supplied to the electric power grid.
12. The system of claim 1, wherein the at least one grid element is
selected from the group consisting of: a sensor, a power-consuming
device, an appliance, a meter, a switch, a controller, a control
device, a power control subsystem integrated with grid element for
supply, a thermostat, a building control system, a security device,
and combinations thereof.
13. The system of claim 1, wherein each of the at least one grid
elements has a unique grid element identifier.
14. The system of claim 13, wherein the unique grid element
identifier comprises IP address, equipment identifier, mac address,
or combinations thereof.
15. The system of claim 13, wherein the unique grid element
identifier further includes location-based factors, time-based
factors, grid-function-based factors, and combinations thereof.
16. The system of claim 1, wherein the financial settlement of the
participation of the at least one grid element is stored in a
database.
17. The system of claim 1, wherein each grid element is registered
with the system and wherein the registration of grid elements is
stored in the databases for predetermined periods of time for use
with the market-based financial settlement associated with the grid
elements.
18. The system of claim 17, wherein information relating to
financial settlement of the participation of the at least one grid
element is stored in a database, and any raw measurement data is
transformed into settled measurements for storage in a
database.
19. The system of claim 17, wherein information relating to grid
elements participation is transformed from raw data into
market-based settlement data, and wherein the market-based
settlement data is stored in a database.
20. The system of claim 1, wherein the settlement message
communicated through the at least one coordinator, the settlement
message further including an IP-based interface that facilitates
communication of the settlement message with the grid elements.
21. The system of claim 20, wherein the IP-based interface is
selected from the group consisting essentially of WiMax, High Speed
Packet Access (HSPA), Evolution for Data Only (EVDO), Long Term
Evolution (LTE), any first or second generation wireless transport
method such as EDGE, or Code Division Multiple Access, Ethernet,
any proprietary Layer 1-4 protocol that contains or is capable of
transporting an Internet Protocol message, and combinations
thereof.
22. The system of claim 1, further comprising a security interface
associated with each of the grid elements operable to receive
security system messages from at least one remotely-located
security system.
23. The system of claim 1, further including a settlement message
having at least one of: a geodetic reference, a grid element
identifier, a grid element type, a grid element function, a grid
element capacity, a grid element profile, a grid element attachment
point reference, a KWP value, a grid element power supply value
(PSV), a grid element power trade block (PTB) value, a grid element
balancing authority association, a grid element owner identifier, a
grid element compatibility identifier, and combinations
thereof.
24. The system of claim 1, wherein the market-based financial
settlement message includes factors for grid stability-based market
pricing, operating reserves-based market pricing, and/or peak and
off-peak timing market pricing.
25. A system for financial settlement of transactions within an
electric power grid network comprising: a settlement processor
comprising a server and/or a processor operatively coupled with a
memory, and a database constructed and configured for electrical
connection and communication via a network with at least one grid
element; wherein each grid element is registered to participate
within the electric power grid; wherein the settlement processor
automatically generates a settlement message used for a
market-based financial settlement for each of the grid element(s)
that includes at least one kilowatt packet (KWP) unit; wherein the
settlement message is transmitted via IP-based messaging; and
wherein the settlement message further includes an IP packet having
information relating to the at least one kilowatt packet (KWP) unit
and revenue grade metrology for the market-based financial
settlement corresponding to the participation of the grid
element(s) within the electric power grid.
26. The system of claim 25, wherein the settlement message is
transmitted to at least one financial institution for implementing
the market-based financial settlement by electronic funds
transfer.
27. A method for financial settlement of transactions within an
electric power grid network comprising the steps of: providing a
settlement processor, comprising a server and/or a processor
operatively coupled with a memory, database, constructed and
configured for electrical connection and IP-based communication via
a network with at least one active grid element; the settlement
processor receiving revenue grade metrology data from the at least
one active grid element that corresponds to its participation in
the electric power grid for load, supply, and/or TDSP; the
settlement processor automatically generating a settlement message
for a market-based financial settlement, and transmitting the
settlement message to at least one of a financial institution, a
market participant, a grid operator, and/or a utility; and the
settlement processor sending or receiving an IP-based message over
the network, the IP-based message further including information
about a financial settlement for participation of at least one grid
element within the electric power grid.
28. The method of claim 27, further including the step of the
settlement processor sending or receiving an IP-based message
including information about at least one grid element participation
in the electric power grid and corresponding kilowatt packet (KWP)
value, power supply value (PSV), and/or power trade block (PTB)
value.
29. A method for financial settlement of transactions within an
electric power grid network comprising the steps of: providing a
settlement processor, comprising a server and/or a processor
operatively coupled with a memory, database, constructed and
configured for electrical connection and IP-based communication via
a network with at least one active grid element; the settlement
processor receiving raw data from the at least one active grid
element corresponding to its participation in the electric power
grid for load, supply, and/or TDSP; the settlement processor
automatically transforming the raw data into settlement grade data;
and the settlement processor automatically generating a settlement
message for a market-based financial settlement, the settlement
message including revenue grade metrology and at least one kiloWatt
packet (KWP) unit for the at least one active grid element that
correspond to its participation in the electric power grid for
load, supply, and/or TDSP.
30. The method of claim 29, further including the step of
transmitting the settlement message to at least one of a financial
institution, a market participant, a grid operator, and/or a
utility.
Description
CROSS-REFERENCES TO RELATED APPLICATIONS
[0001] This application is a continuation of application Ser. No.
13/746,703, filed Jan. 22, 2013, which is a continuation of
application Ser. No. 13/659,564, filed Oct. 24, 2012, both of which
are incorporated herein by reference in their entirety.
BACKGROUND OF THE INVENTION
[0002] 1. Field of the Invention
[0003] The present invention relates generally to the field of
electrical power management systems, and more particularly, to
systems, methods, and apparatus embodiments for electric power grid
and network registration and settlement for participation in energy
supply and/or curtailment as supply, and for energy or capacity
consumption or usage by grid elements.
[0004] 2. Description of Related Art
[0005] Generally, electric power management systems for an electric
power grid are known. However, most prior art systems and methods
apply to normal grid management, macro (large) generation
subsystems, transmission subsystems for transporting high voltage
bulk power to distributions systems where it is sent through
distribution level infrastructure and voltages and finally to end
customers. Prior art to control power load curves include load
curtailment where controls managing the system are used to
deactivate or reduce power supplied to predetermined service points
from the grid. In addition advances in macro-generation and a
transformation from Coal based generation to gas based generation
has led to new (large) gas fired turbines and their associated
subsystems to manage introduction of supply to the grid, but not
particularly operable to smaller distributed supply sources or
methods or technologies introduce a new elements to the grid
wherein those elements are immediately identified, tracked, and
managed within the overall electric grid system for meeting the
needs and/or requirements of an energy management system (EMS)
and/or a distribution management system (DMS) and or generation
management system (GMS) and/or grid governing authority.
[0006] In particular, relevant prior art is known for the
management of traditional large scale energy supply and
technologies associated with transmission, distribution and
consumption of electricity in the power system. Collecting,
transmitting, storing, and analyzing information associated with a
variety of devices associated with the electric power grid is also
known in the art. Settlement for macro energy supply, energy
storage, energy demand, and/or curtailment as supply is known in
the prior art; however, most settlement includes manual and/or
non-real-time settlement including significant estimation or
modeled data where actual data is missing or not collected, and/or
utilization of validation energy equivalence (VEE), and/or
collected and settled over a period of time whereby actual
contributions by sources/suppliers of generation are not fully
known and are estimated and applied to all Market Participants in
some cases a full year after a generation day. In particular,
losses associated with the transmission and distribution is spread
across consumers, also referred by the industry as "loads", by the
utility energy supply provider; where data traditionally has not
available, these inaccuracies within the settlement systems of
prior art place the cost burden for inefficiencies on the consumer
of power, not the utility energy provider and/or
distribution/transmission provider, which is typically the source
of the losses.
[0007] By way of example, relevant prior art documents include the
following:
[0008] U.S. Pat. No. 6,978,931 for "Energy credit card system,"
filed Apr. 13, 2004 and invented by William I. Brobeck, describes a
method of providing an energy credit system for providing
redeemable energy or mass transit credits to consumers who
contribute power to a shared electric power grid, wherein at least
some of the consumers have their own local renewable energy source
connected to the power grid including the steps of measuring the
excess power generated by each consumer's energy source that is fed
into the electric power grid, awarding energy credits to each of
the consumers in relation to the excess power contributed to the
electric power grid by the consumer, allowing each consumer
receiving the energy credits to redeem them by acquiring fuel,
power, or mass transit tickets from a fuel or power provider or
mass transit system, and requiring the operator of the electric
power grid to compensate the fuel for energy provided or mass
transit system in direct relation to the energy credits redeemed by
each consumer. Additionally, it claims recording the credits at an
energy brokerage house, requiring the operator of the power grid to
compensate the brokerage house for the expenses generated by the
consumers, and allowing the brokerage house to retain as profit a
portion of the compensation received from the operator of the power
grid.
[0009] U.S. Pat. No. 6,522,031 for "Power load-leveling system and
packet electrical storage," filed Oct. 10, 2001 and invented by
Povanzana et al., describes a large-scale, capacitor-based
electrical energy storage and distribution system capable of
effectuating load-leveling during periods of peak demand and a cost
savings associated with the purchase of electrical energy; and
disclosing a method of storing and distributing electrical energy
to achieve a cost savings associated with the purchase thereof
including the steps of providing a source of electrical energy,
providing at least one electrical energy storage capacitor capable
of storing a significant amount of energy, the capacitor in
communication with the source, providing control equipment adapted
to analyze and monitor the real-time cost of purchasing electrical
energy from the source and to predict a future cost, supplying an
amount of electrical energy to the capacitor to charge it in
response to a charge signal from control equipment, discharging at
least a portion of the stored energy to a load, and repeating to
maximize cost savings; also disclosing deducting the value of the
electrical energy sold back to the source for any costs of
purchasing energy from the source. See also U.S. Patent Pub. No.
2003/0160595.
[0010] U.S. Patent Pub. No. 2009/0177548 for "Cooperative
environmental and life benefit exchange system," filed Jan. 9, 2009
and invented by Brett F. Eisnlohr, describes a cooperative
environmental and life benefit system including a grid transmitting
available energy, a plurality of rate payers using energy generated
from available energy sources, a plurality of utility companies
providing the grid, a plurality of credits redeemable for acquiring
one or more of a plurality of life benefits, and an administrator
overseeing a redemption process, wherein credits are accumulated by
the rate payers based on either a predetermined amount of
electrical energy purchased from or sold back to the grid; further
describing the redemption process wherein credits accumulated by
the payers are redeemed at a redemption rate to provide a
redemption value, which is remitted by the rate payers to satisfy
benefit cost for acquiring the benefits, or portions thereof.
[0011] U.S. Pat. No. 7,274,975 for "Optimized energy management
system," filed Jun. 6, 2005 and invented by Craig Howard Miller,
describes methods and systems for optimizing the control of energy
supply and demand, including activating battery storage and
alternative energy sources to sell energy to the power grid during
favorable cost conditions, including method steps for allocating
energy at a location where the electrical energy is consumed, with
computer-implemented steps of: determining a marginal cost for each
of a plurality of energy sources available at the location, at
least one of which is a non-grid source of electricity; determining
a capacity of electrical energy available from each non-grid energy
source; determining a demand for electrical energy at the location;
dynamically allocating, in order of lowest marginal cost to highest
marginal cost, electrical energy capacity from each of the
plurality of energy sources to meet the demand; reducing demand at
the location by automatically deferring electrical consumption for
a device for which consumption can be deferred from a higher-cost
time period to a lower-cost time period, including the
computer-implemented step of issuing a command to the device to
cause the deferral to occur, and further including determining
projected marginal costs in each of a plurality of future time
frames and deferring electrical consumption for the device to one
of the plurality of future time frames, while conforming to an
operational constraint for the device, the operational constraint
for the device comprising a maximum time duration for which the
device can be switched off; further including step of determining,
on the basis of time-varying cost of grid-based electrical energy,
whether it is cost-effective to sell electrical energy back to a
grid-based source, and if so, automatically initiating such sale;
and the step of selling electrical energy from a battery to the
grid-based source. See also U.S. Patent Pub. Nos. 2011/0208365 and
2007/0276547.
[0012] U.S. Pat. No. 7,890,436 for "Billing and payment methods and
systems enabling consumer premises equipment," filed Jan. 12, 2007
and invented by Gary Kremen, describes a variety of systems and
methods enabling renewable energy consumer premises equipment (CPE)
such as dual metering techniques, and disclosing supporting by
increasing a likelihood of meeting financing obligations, a
consumer purchasing, leasing, installing, and/or maintaining
renewable energy CPE for power generation at a consumer premises;
coupling the CPE to a power grid operable to receive at least a
portion of the power generated by the CPE, measuring power
generated by the CPE and delivered onto the power grid of a
utility, and processing receivables from the utility associated
with the power generated and delivered onto the power grid directly
to the lender at times corresponding to power measurement to
fulfill the consumer's obligation to repay the loan. See also U.S.
Patent Pub. Nos. 2008/0091581, 2008/0091626, 2008/0091590, and
2008/0091580.
[0013] Additionally, relevant prior art documents associated with
grid elements registration with systems and methods include the
following:
[0014] U.S. Pat. No. 7,502,698 for "Power consumption measuring
device and power control system," filed Jul. 5, 2005 and invented
by Uenou et al., describes a single phase, 3-wire watt-hour meter
that measures power consumption, alters a contract capacity,
controls the stop/start of power supply/distribution, and updates
programs from a higher level control apparatus, including a central
processing unit, a storing means, a communicating means, and
interfaces; the device measures the detailed behavior of a power
consumption by totaling a power consumption every 30 minutes (and a
clocking process for clocking a standard time and for collecting
data within that time), interlocks with a gas leakage detector and
a fire alarm, controls opening/closing of rain doors and the
operation/stop of Internet home electric appliances, and enables
low-cost communication by means of dynamic IP address based
communication.
[0015] U.S. Pat. No. 5,560,022 for "Power management coordinator
system and interface," filed Jul. 19, 1994 and invented by Dunstan
et al., describes a power management system and interface providing
a flexible and uniform protocol for controlling power management
within a computer system including various software layers and
add-in components; a programmable power policy manager, which
allows user to define a performance/economy setting for the system
that is communicated to all registered devices so that dwell and
decay times are set by the device; and a programmable event
sequencer, which maintains an event notification sequence and
control sequence for power events; a programmable power budgeter
that maintains and allocates power on a request basis for system
elements; a programmable thermal budgeter that maintains and
allocates energy based on thermal considerations; and a computer
system including a bus for communicating address and data
information, a central processor couple to the bus for executing
instructions and processing data, and memory coupled to the bus for
containing information, and a power management coordinator that
includes a power management core for communication of power
management information with system devices within the computer
system under a uniform power management protocol, wherein
particular devices are add-in devices requiring power management,
and one of the devices provides programmable dwell time and decay
time periods for power management of the add-in devices, wherein
power events are generated by clients and broadcast by power
management core to power management clients, including a power
event sequencer for maintaining a particular sequence of
communication about the power events.
[0016] U.S. Pat. No. 8,095,233 for "Interconnected premises
equipment for energy management," filed Oct. 10, 2006 and invented
by Shankar et al., describes a system for facilitating direct
monitoring and control of energy-consuming appliances, in real
time, using automatic programmatic control and a plurality of human
interfacing including local display and control, email, web
browser, text messaging, and integrated voice response, and
describing a monitoring and control coordinator that provides
centralized coordination of functions and one or more communicating
appliance interfaces that interact with energy consuming appliances
that are interconnected via wired and wireless communication
networks and protocols, wherein the system allows a user to
regulate energy consumption of a premises for heating and air
conditioning systems, including a premises control communication
gateway in communication with the monitoring and control
coordinator.
[0017] U.S. Pat. No. 6,301,528 for "Method and device for
controlling electric consumers in a motor vehicle," filed Sep. 25,
1999 and invented by Bertram et al., describes a method and an
arrangement for controlling electric consumers in a vehicle that
are suggested with a control structure provided for consumers, the
control structure including at least a high-ranking consumer
management that receives requests from the consumers with respect
to consumer power individually or as sums; the control structure
including a coordinator for the vehicle electrical system and power
generation therefor, and for receiving the sum of the requested
consumer power from the consumer management; the vehicle electric
system adjusting the requested electric power via orders to the
vehicle electrical system components and the consumer management
taking the generated electrical power via control of the
consumers.
[0018] U.S. Patent Pub. No. 2007/0067132 for "Method and apparatus
for routing data streams among intelligent electronic devices,"
filed Sep. 19, 2006 and invented by Tziouvaras et al., discloses an
intelligent electronic device (IED) for protection, monitoring,
controlling, metering, or automation of lines in an electrical
power system, wherein the IED is adapted to communicated with a
variety of other IEDs, including a communication configuration
setting that is configured to allow communication with one of the
other IEDs; and further including an input element in communication
with the communication configuration setting, whereupon a signal
from the input element selects a particular communication
configuration setting therein, allowing for the communication with
other IEDs. Also, including a data stream management device for
routing data streams among IEDs associated with the electrical
power system, wherein the data streams are substantially unaltered
from sent and received forms, and an IED associated with the data
stream management device and adapted to communicate with the other
IEDs, wherein assertion of an input element selects a particular
communication configuration setting.
[0019] U.S. Pat. No. 7,609,158 for "Electrical power system control
communications network," filed Oct. 26, 2006 and invented by
Banting et al., describes a communications network for an
electrical power distribution system, the network communicating
monitoring signals and control signals for a network of electrical
circuits, the network including a sensor node with a sensor device
configured to detect an operating condition of the transmission or
distribution systems, a sensor communication node corresponding to
the sensor device, and configured to transmit a first wireless
signal corresponding to the detected operating condition of
transmission/distribution, a control communication node separately
provided from the sensor communication node, configured to receive
the first wireless signal and transmit a second wireless signal
corresponding to the first wireless signal, a gateway device in
communication with the control communication node and receiving the
second wireless signal, and wherein the sensed electrical signals
are broadcast.
[0020] U.S. Pat. No. 8,060,259 for "Wide area, real time monitoring
and visualization system," filed Jun. 15, 2007 and invented by
Budhraja et al., describes a real-time performance monitoring
system for monitoring an electrical power grid, including grid
portions having control areas, and monitoring of reliability
metrics, generations metrics, transmission metrics, suppliers
metrics, grid infrastructure security metrics, and markets metrics
for the electric power grid, wherein the metrics are stored in a
database, and visualization of the metrics is displayed on a
computer having a monitor.
[0021] U.S. Patent Pub. No. 2009/0119039 for "Approach for
Controlling Electrical Power," filed Nov. 7, 2007 and invented by
Banister et al., describes an electrical power metering system
including a plurality of gated power receptacles, each of them
being configured to selectively provide electrical power in
response to receiving a wireless signal, and further including a
service application configured to receive a request to provide
electrical power for one of the receptacles, the request including
an identifier that designates the receptacle at which power is
requested. A local host application executable on a computing
device is configured to send wireless signals via a coordinator
module to the receptacle to provide power in response to receiving
a communication from the service application that includes the
identifier.
[0022] In the area of managing supply of energy to the grid,
detailed attachment modeling is required; also, due to the
requirements that any amount of supply, even micro-scale supply,
must comply with standards applicable to full scale utilities or
macro-generation supply, this compliance is difficult and
expensive. However, there are relevant prior art documents relating
to management electric power grids in the field of the present
invention. By way of example, consider the following U.S. patent
and U.S. patent Publication documents:
[0023] U.S. Pat. No. 5,560,022 for "Power management coordinator
system and interface," filed Jul. 19, 1994 and invented by Dunstan
et al.
[0024] U.S. Pat. No. 6,301,528 for "Method and device for
controlling electric consumers in a motor vehicle," filed Sep. 25,
1999 and invented by Bertram et al.
[0025] U.S. Pat. No. 7,502,698 for "Power consumption measuring
device and power control system," filed Jul. 5, 2005 and invented
by Uenou et al.
[0026] U.S. Pat. No. 8,095,233 for "Interconnected premises
equipment for energy management," filed Oct. 10, 2006 and invented
by Shankar et al.
[0027] U.S. Patent Pub. No. 2007/0067132 for "Method and apparatus
for routing data streams among intelligent electronic devices,"
filed Sep. 19, 2006 and invented by Tziouvaras et al.
[0028] U.S. Patent Pub. No. 2008/0040479 for "Connection Locator in
a Power Aggregation System for Distributed Electric Resources,"
filed Aug. 9, 2007 and invented by Bridge et al., discloses a
method to obtain the physical location of an electric device, such
as an electric vehicle, and transforming the physical location into
an electric network location, and further including receiving a
unique identifier associated with a device in a physical location.
See also related International Patent Pub. No. WO2008073477 and
U.S. Patent Pub. Nos. 2009/0043519, 2009/0200988, 2009/0063680,
2008/0040296, 2008/0040223, 2008/0039979, 2008/0040295, and
2008/0052145.
[0029] International Patent Pub. No. WO2011/079235 for "Distributed
energy source system," filed Dec. 22, 2010 and invented by Kevin
Williams, describes an energy management system that includes
distributed energy sources (for example a wind turbine) that
communicate with consumer devices and electric utilities, wherein a
CPU is in communication with the distributed energy source and is
operable to control the flow of energy produced by the distributed
energy source.
[0030] International Patent Pub. No. WO2012/015508 for "Dynamic
distributed power grid control system," filed May 2, 2011 and
invented by Cheman et al., describes a control system for a
distributed power grid that includes a simulation module operative
to directly interface with the operational control of the
distributed energy resources (DER) to develop and dynamically
modify the control inputs of the distributed power grid, and
wherein the distributed control module can simulate control
response characteristics of the DER to determine control
methodology by conducting decentralized and distributed simulation.
See also International Patent Pub. Nos. WO2012/00879 and
WO2012/015507, and U.S. Patent Pub. Nos. 2011/0106321,
2012/0029720, and 2012/0029897.
[0031] International Patent Pub. No. WO2012/058114 for "Method and
system facilitating control strategy for power electronics
interface of distributed generations resources," filed Oct. 21,
2011 and invented by Alatrash et al., discloses a method and system
for implementing a control strategy for distributed generation (DG)
units, wherein the DG unit behaves similarly to a synchronous
generator.
[0032] U.S. Pat. No. 7,949,435 for "User interface and user control
in a power aggregation system for distributed electric resources,"
filed Aug. 9, 2007 and invented by Pollack et al., describes a
method and operator interface for users or owners of a distributed
power resource, such as an electric vehicle, which connects to a
power grid, wherein the user or owner controls a degree of
participation of the electric resource power aggregation via the
user interface, and further including an energy pricing preference,
a vehicle state-of-charge, and a predicted amount of time until the
electric resource disconnects from a power grid. See also U.S.
Patent Pub. Nos. 2009/0043520 and 2008/0039989.
[0033] U.S. Patent Pub. No. 2011/0282511 for "Prediction,
Communication and Control System for Distributed Power Generation
and Usage," filed Mar. 26, 2011 and invented by Richard Thomas
Unetich, describes an apparatus for obtaining, interpreting and
communicating a user reliable and predictive information relevant
to the price of electricity service at a prospective time.
[0034] U.S. Pat. No. 7,844,370 for "Scheduling and control in a
power aggregation system for distributed electric resources," filed
Aug. 9, 2007 and invented by Pollack et al., describes systems and
methods for a power aggregation system in which a server
establishes individual Internet connections to numerous electric
resources intermittently connect to the power grid, such as
electric vehicles, wherein the service optimizes power flows to
suit the needs of each resource and each resource owner, while
aggregating flows across numerous resources to suit the needs of
the power grid, and further including inputting constraints of
individual electric resources into the system, which signals them
to provide power to take power from a grid.
[0035] U.S. Patent Pub. No. 2009/0187284 for "System and Method for
Providing Power Distribution System Information," filed Jan. 17,
2009 and invented by Kreiss et al., describes a computer program
product for processing utility data of a power grid, including a
datamart comprised of physical databases storing utility data
applications comprising an automated meter application configured
to process power usage data from a plurality of automated meters, a
power outage application configured to identify a location of a
power outage, and a power restoration application configured to
identify a location of a power restoration. See also U.S. Patent
Pub. Nos. 2011/0270550, 2011/0270457, and 2011/0270454.
[0036] The increased awareness of the impact of carbon emissions
from the use of fossil fueled electric generation combined with the
increased cost of producing base load, intermediate, and peak power
during high load conditions has increased the need for alternative
solutions utilizing new power technologies as a mechanism to defer,
or in some cases eliminate, the need for the deployment of
additional macro generation capacity by electric utilities,
generating utilities, or distributing utilities or any grid
operator or market participant whose primary function is to
facilitate the production, distribution, operation and sale of
electricity to individual consumers. Existing electric utilities
are pressed for methods to defer or eliminate the need for
construction of fossil-based or macro large scale electricity
generation while dealing with the need to integrate new sources of
generation such as renewable energy sources or distributed energy
resources whose production and integration into the electric grid
is problematic.
[0037] Today, a patchwork of systems exist to dispatch macro
generation, implement demand response load management programs,
dispatch of intermittent renewable resources, and energy management
and control. These legacy systems are used for both supplying
"negawatts", supply and grid stability to the electric utility
grid. In the case of demand management, also referred to in the
industry as "Demand Response", various radio subsystems in various
frequency bands utilize "one-way" transmit only methods of
communication or most recently deployed a plurality of proprietary
two-way methods of communications with electric customers or their
load consuming device and measurement instruments including, by way
of example, "smart meters." In addition, macro generation is
controlled and dispatched from centralized control centers either
from utilities, Independent Power Producers (IPPs) or other Market
Participants that utilize point to point primarily "Plain old
telephone service" POTS dedicated low bit rate modems or nailed
time division multiplex (TDM) circuits such as T-1s that supply
analog telemetry to Energy Management Systems or in some cases
physical dispatch to a human operator to "turn on" generation
assets in response to grid supply needs or grid stress and high
load conditions. These legacy systems operate under a framework
supported for decades to attempt to increase the efficiency of
existing transmission infrastructure and simultaneously attempt to
supply each grid operator, Market Participant or end customer the
lowest cost of energy regardless of the type of resource.
Unfortunately, these legacy systems, in the industry referred to as
"Security Constrained Economic Dispatch" (SCED) utilize complex
models with incomplete information to provide both ISOs and
Traditional Utilities a means to provide a generation forecast for
the next generation time period (for example, day ahead).
[0038] SCED has not been successful in the facilitation of new
technologies such as Demand Management, Advanced Curtailment
contemplated under FERC Order 745, Advanced Storage contemplated
under FERC Order 750, or Advanced Distributed Energy Resources
contemplated under FERC Order 755.
[0039] Existing uses for traditional Demand Response technologies,
that are not generally capable of performing to the level
contemplated under FERC Order 745, but are used for peak shaving,
utilities or other market participants install radio frequency
(RF)-controlled relay switches typically attached to a customer's
air conditioner, water heater, or pool pumps, or other individual
load consuming devices. A blanket command is sent out to a specific
geographic area whereby all receiving units within the range of the
transmitting station (e.g., typically a paging network) are turned
off during peak hours at the election of the power utility. After a
period of time when the peak load has passed, a second blanket
command is sent to turn on those devices that have been turned off.
This "load shifting" has the undesired effect of occasionally
causing "secondary peaks" and generally requires consumer
incentives for adoption. Furthermore integrating even these simple
load shifting assets for purposes of settlements is problematic
given that these traditional technologies cannot provide the
necessary geodetic, PSV, and other information necessary for these
load sources to be integrated into an Energy Management System or
settled under the traditional energy dispatch and settlement
systems.
[0040] Most recent improvements that follow the same concepts for
Demand Response are RF networks that utilize a plurality of mesh
based, non-standard communications protocols that utilize IEEE
802.15.4 or its derivatives, or "ZigBee" protocol end devices to
include load control switches, programmable thermostats that have
pre-determined set points for accomplishing the "off" or "cut" or
reduce command simultaneously or pre-loaded in the resident memory
of the end device. These networks are sometimes referred to in the
industry as "Home Area Networks" or (HANs). In these elementary and
mostly proprietary solutions, a programmable control thermostat(s)
(PCTs) or building management systems (BMS) move the set point of
the HVAC (or affect another inductive or resistive device) or
remove a resistive device from the electric grid thus accomplishing
the same "load shifting" effect previously described. All of these
methods require and rely on statistical estimations and modeling
for measuring their effectiveness and use historical information
that are transmitted via these same "smart meters", interval device
recorders (IDRs), or revenue grade meters, to provide
after-the-fact evidence that an individual device or consumer
complied with the demand response or market driven event. Protocols
that are employed for these methods include "Smart Energy Profiles
Versions 1 & 2" and its derivatives to provide utilities and
their consumers an attempt at standardization amongst various OEMs
of PCTs, switching, and control systems through a plurality of
protocols and interfaces. These methods remain crude and do not
include real time, measurement, verification, settlement and other
attributes necessary to have their Demand Response effects utilized
for effective Operating Reserves with the exception of limited
programs for "Emergency" Capacity Programs as evidenced by programs
such as the Energy Reliability Council of Texas'(ERCOT's) Emergency
Interruptible Load Service (EILS). Furthermore, for effective
settlement and control of mobile storage devices such as Electric
Vehicles, these early "Smart Grid" devices are not capable of
meeting the requirements of Federal Energy Regulatory Commission
(FERC), North American Electric Reliability Corp. (NERC) or other
standards setting bodies such as the National Institute of Science
& Technology (NIST) Smart Grid Roadmap.
[0041] While telemetering has been used for the express purpose of
reporting energy usage in real time, no cost effective techniques
exist for calculating power consumption, carbon gas emissions,
sulfur dioxide (SO.sub.2) gas emissions, and/or nitrogen dioxide
(NO.sub.2) emissions, and reporting the state of a particular
device under the control of a two-way positive control load
management device or other combinations of load control and
generator controls as previously described. In particular, one way
wireless communications devices have been utilized to de-activate
electrical appliances, such as heating, ventilation, and
air-conditioning (HVAC) units, water heaters, pool pumps, and
lighting or any inductive or resistive device that is eligible as
determined by a utility or market participant for deactivation,
from an existing electrical supplier or distribution partner's
network. These devices have typically been used in combination with
wireless paging receivers or FM radio carrier data modulation, or a
plurality of 2-way proprietary radio frequency (RF) technologies
that receive "on" or "off" commands from a paging transmitter or
transmitter device. Additionally, the one-way devices are typically
connected to a serving electrical supplier's control center via
landline trunks, or in some cases, microwave transmission to the
paging transmitter. The customer subscribing to the load management
program receives a discount or some other form of economic
incentive, including direct payments for allowing the serving
electrical supplier (utility), retail electric provider or any
other market participant to connect to their electrical appliances
with a one-way load control switch and deactivate those appliances
during high energy usage or high energy price periods. This
technique of demand response is used mostly by utilities or any
market participant for "peak shifting" where the electric load
demand curve is moved from a peak period to a less generation
intensive time interval and are favored by rate-based utilities who
earn capital returns of new power plants or any capital deployed to
operate their electric grids that are approved by corresponding
Public Utility Commissions. These methods are previous art and
generally no conservation of energy is measured. In many instances,
secondary peak periods occur when the cumulative effect of all the
resistive and inductive devices are released from the "off" state
simultaneously causing an unintended secondary peak event, also
known as a flash back event.
[0042] While one-way devices are generally industry standard and
relatively inexpensive to implement, the lack of a return path from
the receiver, combined with the lack of information on the actual
devices connected to the receiver, make the system highly
inefficient and largely inaccurate for measuring the actual load
shed to the serving utility or compliant with measurement and
verification for presenting a balancing authority or independent
system operator for operating reserves and settlements. While the
differential current draw is measurable on the serving electric
utility's transmission lines and at electrical bus or substations,
the actual load shed is approximate and the location of the load
deferral is approximated at the control center of the serving
utility or other statistical methods are considered to approximate
the individual or cumulative effect on an electric utility grid.
The aforementioned "two-way" systems are simultaneously defective
in addressing real time and near real time telemetry needs that
produce generation equivalencies that are now recognized by FERC
Orders such as FERC 745 where measurable, verifiable Demand
Response "negawatts", defined as real time or near real time load
curtailment where measurement and verification can be provided
within the tolerances required under such programs presented by
FERC, NERC, or the governing body that regulate grid operations.
The aforementioned "smart meters" in combination with their data
collection systems commonly referred to as "Advanced Metering
Infrastructure" (AMI) generally collect interval data from meters
in HISTORICAL fashion and report this information to the utility,
market participant or grid operator AFTER the utility or grid
operator has sent notice for curtailment events or "control events"
to initiate due to high grid stress that includes lack of adequate
operating reserves to meet demand, frequency variations, voltage
support and any other grid stabilizing needs as identified by the
utility or grid operator and published and governed by FERC, NERC,
or other applicable regulations. Standard AMI meters report
historical information at least 15 minutes after the event
occurred, but the time lag could be as long as 24 hours.
[0043] One exemplary telemetering system is disclosed in U.S. Pat.
No. 6,891,838 B1. This patent describes details surrounding a mesh
communication of residential devices and the reporting and control
of those devices, via WANs, to a computer. The stated design goal
in this patent is to facilitate the "monitoring and control of
residential automation systems." This patent does not explain how a
serving utility or customer could actively control the devices to
facilitate the reduction of electricity. In contrast, this patent
discloses techniques that could be utilized for reporting
information that is being displayed by the serving utility's power
meter (as do many other prior applications in the field of
telemetering).
[0044] An additional exemplary telemetering system is disclosed in
U.S. Patent Application Publication No. 2005/0240315 A1. The
primary purpose of this published application is not to control
utility loads, but rather "to provide an improved interactive
system for remotely monitoring and establishing the status of a
customer utility load." A stated goal of this publication is to
reduce the amount of time utility field personnel have to spend in
the field servicing meters by utilizing wireless technology.
[0045] Another prior art system is disclosed in U.S. Pat. No.
6,633,823, which describes, in detail, the use of proprietary
hardware to remotely turn off or turn on devices within a building
or residence. While initially this prior art generally describes a
system that would assist utilities in managing power load control,
the prior art does not contain the unique attributes necessary to
construct or implement a complete system. In particular, this
patent is deficient in the areas of security, load accuracy of a
controlled device, and methods disclosing how a customer utilizing
applicable hardware might set parameters, such as temperature set
points, customer preference information, and customer overrides,
within an intelligent algorithm that reduces the probability of
customer dissatisfaction and service cancellation or churn.
[0046] Attempts have been made to bridge the gap between one-way,
un-verified power load control management systems and positive
control verified power load control management systems. However,
until recently, technologies such as smart breakers and command
relay devices were not considered for use in residential and
commercial environments primarily due to high cost entry points,
lack of customer demand, and the cost of power generation relative
to the cost of implementing load control or their ability to meet
the measurement, telemetry, verification requirements of the grid
operator or ISO. Furthermore, submetering technology within the
smart breaker, load control device, command relay devices or
building control systems have not existed in the prior art.
[0047] One such gap-bridging attempt is described in U.S. Patent
Application Publication No. US 2005/0065742 A1. This publication
discloses a system and method for remote power management using
IEEE 802 based wireless communication links. The system described
in this publication includes an on-premise processor (OPP), a host
processor, and an end device. The host processor issues power
management commands to the OPP, which in turn relays the commands
to the end devices under its management. While the disclosed OPP
does provide some intelligence in the power management system, it
does not determine which end devices under its control to turn-off
during a power reduction event, instead relying on the host device
to make such decision. For example, during a power reduction event,
the end device must request permission from the OPP to turn on. The
request is forwarded to the host device for a decision on the
request in view of the parameters of the on-going power reduction
event. The system also contemplates periodic reading of utility
meters by the OPP and storage of the read data in the OPP for later
communication to the host device. The OPP may also include
intelligence to indicate to the host processor that the OPP will
not be able to comply with a power reduction command due to the
inability of a load under the OPP's control to be deactivated.
However, neither the host processor nor the OPP determine which
loads to remove in order to satisfy a power reduction command from
an electric utility, particularly when the command is issued by one
of several utilities under the management of a power management
system. Further, neither the host processor nor the OPP tracks or
accumulates power saved and/or carbon credits earned on a per
customer or per utility basis for future use by the utility and/or
customer. Still further, the system of this publication lacks a
reward incentive program to customers based on their participation
in the power management system. Still further, the system described
in this publication does not provide for secure communications
between the host processor and the OPP, and/or between the OPP and
the end device. As a result, the described system lacks many
features that may be necessary for a commercially viable
implementation.
[0048] Customer profiles are often used by systems for a variety of
reasons. One reason is to promote customer loyalty. This involves
keeping information about not only the customer, but about the
customer's actions as well. This may include information about what
the customer owns (i.e., which devices), how they are used, when
they are used, device energy consumption, device operational costs,
etc. By mining this data, a company can more effectively select
rewards for customers that give those customers an incentive for
continuing to do business with the company. Similar actions are
famously performed by Walmart on customers buying habits to predict
supply chain management. This is often described as customer
relationship management (CRM).
[0049] Customer profile data is also useful for obtaining feedback
about how a product is used or how small distributed energy sources
may be dispatched back to the electric power grid. In software
systems, this is often used to improve the customer/user experience
or as an aid to testing or to set pricing parameters for deploying
distributed energy resources. Deployed systems that have customer
profiling communicate customer actions and other data back to the
development organization. That data is analyzed to understand the
customer's experience. Lessons learned from that analysis is used
to make modifications to the deployed system, resulting in an
improved system.
[0050] Customer profile data may also be used in marketing and
sales. For instance, a retail business may collect a variety of
information about a customer, including what customers look at
on-line and inside "brick-and-mortar" stores. This data is mined to
try to identify customer product preferences and shopping habits.
Such data helps sales and marketing determine how to present
products of probable interest to the customer, resulting in greater
sales.
[0051] However, the collection of customer profile information by
power utilities, retail electric providers or any other market
participant that sells retail electric commodity to end customers
(residential or commercial) has been limited to customer account
information of gross electrical consumption and inferential
information about how power is being consumed but requires
customers to take their own actions. Because power utilities, REPs,
market participants typically are unable to collect detailed data
about what is happening inside a customer's home or business,
including patterns of energy consumption by device, there has been
little opportunity to create extensive customer profiles.
[0052] Thus, none of the prior art systems, methods, or devices
provide complete solutions for financial settlement associated with
power management, including grid elements and network management,
and settlement for grid element participation in supplying and/or
receiving power from the electric power grid, including messaging
over communication networks and energy management over the electric
power grid network, wherein the grid elements are attached to the
electric grid and registered therewith. Therefore, a need exists
for systems and methods for grid element participation settlement
and management to overcome the shortcomings of the prior art.
SUMMARY OF THE INVENTION
[0053] The present invention provides systems, methods, and
apparatus embodiments for electric power grid and network
registration and management of grid elements, their participation
in the electric power grid, and financial settlement for grid
element participation in the electric power grid, the financial
settlement including compensation and/or payment relating to that
participation in real-time and/or less than about 15 minute
settlement intervals. Accordingly, grid elements are transformed
into active grid elements following initial registration of each
grid element with the system, preferably through network-based
communication between the grid elements, a Coordinator, a
translator, and a settlement processor. Also preferably, messaging
is managed through a network by a Coordinator using IP messaging
for communication with the grid elements, with the energy
management system (EMS), Distribution Management System (DMS), and
with the utilities, market participants, and/or grid operators.
Furthermore, the Coordinator is operable for receiving information
communicated from grid elements, authenticating, and registering
grid elements, and for receiving and communicating data associated
with the participation for supply, curtailment as supply, and/or
consumption of electric power from the grid, and settlement
associated with that participation for each of the grid elements,
again as contemplated by the aforementioned and any follow on FERC
or NERC Order that is meant to influence resources for capacity,
energy, energy equivalents, micro/macro generation, storage
technologies, transmission capacities, grid elements, ancillary
services, settlement intersections know and defined or those
defined through the implementation of this art, thereby
transforming real-time or less than about 15 minute interval data
into automated settlement. The Coordinator is further operable for
communicating data with a database, a persistence layer or cache,
an ASIC or memory contained in a grid element or the processor, or
combinations thereof and to provide an overall assessment of
electric grid operations (normal or emergency) including but not
limited to energy flows within the system, grid stabilization
information, operating reserves, capacity, transmission and
distribution capacities, grid element capacities, settlement, and
combinations thereof.
[0054] Following registration, the multiplicity of active grid
elements function in the grid for control, reporting, status, grid
operations (normal or emergency), any source of macro supply
capacity/energy, supply as distributed energy resources from a
plurality of methods, supply/energy through storage devices, and/or
load curtailment as supply or capacity, wherein the registered,
active grid elements and their corresponding activities and
information associated with those activities deliver electric
supply to the electric grid, curtail load sources, control active
or passive grid elements used in the operation of the grid, or any
other device that is attached to the electric grid for its normal
or emergency functions and are tracked and managed in accordance
with regulations and standards governing the electric power grid.
Reporting and tracking status of those grid elements with and
through the coordinator or the coordinator in communication with
legacy grid operator subsystems is also important in determining
settlements for the aforementioned use cases. When grid elements
are inactive, unanticipated outages, growth or changes in the
electric grid, replacement of defective or upgrades to grid
elements or a portion of the transmission or distribution system
becomes inactive for a plurality of reasons (grid element outage),
the impact of these changes in normal grid operation will impact
settlements for those Market Participants or individual sources of
supply, curtailment and their associated settlements inclusive of
grid elements.
[0055] Accordingly, one aspect of the present invention is to
provide a system for electric power grid network management
including: at least one grid element constructed and configured for
electrical connection and network-based communication with a server
and/or a processor operatively coupled with memory; wherein the
grid element is transformed into at least one active grid element
after initial connection with the server and/or the processor
operatively coupled with the memory via a network, preferably a
communications network, wherein the registration is preferably
automatic and/or autonomous.
[0056] Another aspect of the present invention is to provide an
apparatus for smart electric power grid communication including: a
grid element constructed and configured for electrical connection
and network-based communication with a server associated with an
electric power grid; wherein the grid element is transformed into
an active grid element after initial connection with the electric
power grid, and preferably wherein each active grid element has a
unique identifier. By way of example and not limitation, at least
one of the grid elements is a control device that operates,
programs and updates select load consuming device(s) or generating
devices associated with the electric power grid (including but not
limited to control systems, thermostats, controllers, anything that
controls the device, switch gear, large control systems operating
from a control center or box with interface to a large control
system, such as a distribution automation control system;
transformation process includes whatever control systems are
attached to the electric devices, their databases, tables, memory,
ASICs, firmware, software, operating systems, and combinations
thereof and/or other grid elements).
[0057] Also, in one aspect of the present invention a method for
electric power grid network management is provided, including the
steps of: providing at least one grid element constructed and
configured for electrical connection and network-based
communication with a server; the at least one grid element
communicating a message to the server, wherein the message is
preferably standards-based or proprietary; the at least one grid
element automatically connecting to at least one other active grid
element for functioning actively within the electric power grid,
wherein the at least one grid element makes an initial connection
with the server via a network. Also, methods may further include
the step of: connecting the at least one grid element to an
electric power grid. Also preferably, the at least one grid element
is operable for sending and/or receiving a message via
communication with the server via a network, and the message is
routed by a coordinator to the server. Messages are sent via the
network and include Internet Protocol (IP)-based messaging, which
provides for secure communication, for example using encryption,
private networks, or IP encapsulation over proprietary networks.
The present invention thus preferably provides secure
communications, which are improved over the prior art's use of
analog telemetry such as in outage detection systems, and telemetry
sub-systems.
[0058] These and other aspects of the present invention will become
apparent to those skilled in the art after a reading of the
following description of the preferred embodiment when considered
with the drawings, as they support the claimed invention.
BRIEF DESCRIPTION OF THE DRAWINGS
[0059] FIG. 1 is a schematic diagram illustrating settlement
processor systems and methods of the present invention including
grid elements, coordinator, translator, and settlement processor
components.
[0060] FIG. 2 is a schematic diagram illustrating a virtualized
computing network used in one embodiment of the invention for
automated systems and methods.
[0061] FIG. 3 is a schematic diagram illustrating a coordinator and
grid elements within the systems and methods of the present
invention.
[0062] FIG. 4 is a schematic diagram illustrating grid elements,
attachment points, and telemetry through a network associated with
the systems of the present invention.
[0063] FIG. 5 is a schematic diagram illustrating an exemplary
network node configuration for grid elements registration and
communication.
[0064] FIG. 6 is a schematic diagram illustrating a distribution
automation communications network.
[0065] FIG. 7 is a schematic diagram showing energy system
operations and communications via network-based connections.
[0066] FIG. 8 is a schematic diagram showing a basic Automated
Generator Control (AGC)/energy management system (EMS)/distribution
management system (DMS) representation.
DETAILED DESCRIPTION OF THE PRESENT INVENTION
[0067] By way of background context for financial settlement
systems under existing market rules for electric power grids, any
generation supplier, including Market Participants (supplier), may
elect to participate in an economic dispatch for supplying electric
power or Operating Reserves to the electric power grid. For
example, Pennsylvania, Jersey, Maryland Independent System Operator
(ISO), (PJM) is a non-profit entity that provides for economic
dispatch; PJM Interconnection (PJM) is a regional transmission
organization (RTO) that coordinates the movement of wholesale
electricity in all or parts of several states within the USA
(www.pjm.com). Acting as a neutral, independent party, PJM operates
a competitive wholesale electricity market and manages the
high-voltage electricity grid to ensure reliability for millions of
customers in the USA under the jurisdiction of the Federal Energy
Reliability Commission (FERC). Under the current system, the
supplier submits voluntary price and quantity bid(s) on a day-ahead
basis or real-time basis, specifying the price(s) the supplier is
willing to accept within a predetermined or specified range of
output(s). Voluntary price and quantity bids supersede PJM's
previous reliance on cost-based estimates. Suppliers have equal
access to all wholesale loads served, and PJM's bidding and
dispatch rules apply uniformly, without regard to suppliers'
ownership or affiliation. Note, however, that prior art systems and
methods fail to provide equal access to all suppliers, particularly
those suppliers who do not provide at least a minimum level of
supply quantity; this is one reason that distributed power systems
and methods fail to provide for reasonable market-based settlement
for all suppliers, regardless of volume or quantity of supply.
[0068] By contrast to the prior art, the systems and methods of the
present invention provide for aggregation of suppliers until at
least the minimum acceptable quantity is reached, i.e., a power
trading block (PTB) unit (minimum) is reached or achieved by the
aggregation of suppliers distributed who are willing to supply and
accept at predetermined market pricing levels. Thus the present
invention advantageously provides for market-pricing-based
settlement for all suppliers, even those who are willing and able
to supply an amount less than the minimum, since the aggregation of
a multiplicity of suppliers' quantity into a minimum PTB unit is
realized under the systems and methods of the present
invention.
[0069] Furthermore, on the basis of voluntary price and quantity
bids received, PJM determines market clearing prices at each
location or node on the electric power grid, i.e., locational
marginal prices (LMP) based upon the marginal cost of serving the
last increment of load at each location. Market clearing prices are
paid to all suppliers participating in the economic dispatch, while
differences in locational prices between the point of withdrawal
and the point of injection of electrical power into the electrical
power grid are used to price the transmission between those points
and to account for congestion in transmission and distribution of
the power in the grid. After reviewing all scheduled and actual
flows on the grid, PJM adjusts generation and loads as needed to
maintain frequency, equilibrium between loads and resources, and
meet voltage and other reliability constraints. To relieve
transmission constraints, PJM is required from time to time to
dispatch generation out of merit order.
[0070] Additionally, and alternatively to integrating with existing
PJM-based or legacy-based settlement systems and methods for
improving settlement accuracy and for providing grid
element-specific settlement data, real-time or near-real time (less
than about 15 minute intervals) bidding and acceptance is provided
under the systems and methods of the present invention, thereby
providing an automated clearinghouse for grid element participation
in electric power supply to the electric power grid on a real-time
or near-real-time (less than 15 minute interval) basis, or any
sub-increment of time required for settlement of curtailment
technologies as contemplated by FERC Order 745 (137 FERC 61,215
issued Dec. 15, 2011 and 134 FERC 61,187 issued Mar. 15, 2011),
incorporated herein by reference in its entirety, which one not
skilled in the art could reduce to "Negawatts equals Megawatts" for
purposes of compensation. Any sub-increment of time as contemplated
by FERC Order 750 (135 FERC 61,041 issued Apr. 21, 2011) and FERC
Order 755 and 755-A (755 can be found at 137 FERC 61,064 issued
Oct. 20, 2011; 755-A can be found at 138 FERC 61,123 issued Feb.
16, 2012), both Orders being incorporated herein by reference in
their entirety, which one not skilled in the art could reduce to a
general description as ANY micro or macro supply source that
provides capacity, energy, and grid stability via its operation may
be paid the clearing price for providing this energy resource at
the nearest clearing location, which could be a resource node, a
LMP, a utility service boundary, a balancing authority, a
transmission intersection, a point where metering defines a
boundary between two Market Participants as defined by FERC, NERC,
ISO, or any governing body that regulates matters associated with
the electric power grid. Furthermore, to facilitate advanced
settlements, the automatic registration of any grid element is
essential for the automated settlement under the present
invention.
[0071] At the time of the present invention, the electric power
grid provides for pricing and settlement based upon the market
pricing on at least a one-day-ahead basis. However, because of
newly issued FERC orders 745, 750, 755, micro and macro
technologies evolving for meeting the requirements of FERC 755
would require improved timing of pricing and settlement.
[0072] Advanced Settlements Overview
[0073] To address the shortcomings of the prior art and to meet
these requirements, the present invention provides for real-time
and/or near-real-time pricing and settlement in less than the
day-ahead basis provided in the prior art, and more preferably less
than about 15 minute intervals. IP-based messaging communications
from grid elements as suppliers and through corresponding
coordinators, the registered grid elements may participate in
offering on a geodetic basis from specified nodes or attachment
points associated with the electric grid, pricing and quantity
available on the real-time and/or near-real-time basis, which is
preferably automatically accepted by market participants through
the communications system and energy routing systems and methods of
the present invention.
[0074] The present invention further provides for a resource
settlement point or resource settlement node, which provides for
the location of the settlement of the grid element for
participation in the electric power grid. It functions as the
attachment point for the grid element, and it can be either static
or dynamic, i.e., it may provide for the grid element participation
location at or across the intersection of transmission boundaries,
utility service areas, and provides that the grid element itself
serves as a point of demarcation for settlement of financial
transactions for load, supply, transmission, capacity; the resource
settlement point or resource settlement node is determined by the
governing entity, and is changeable or dynamic, for example, by the
TDSP. For batteries, or mobile supply or storage device, such as by
way of example and not limitation, electric vehicles, which are
mobile and attach to the electric power grid for consuming power
(charging) and/or supplying power (discharging), the resource
settlement point or resource settlement node, is dynamic, and is
preferably reported through the coordinator, and then translated
back to the legacy systems, such that the mobile grid element (in
this example, an electric vehicle) becomes the financial settlement
point, and is moveable to more than one location at the grid, for
supply and/or demand or consumption of energy. The resource service
node functions to route or change the routes depending upon the
congestion detected within the transmission or distribution of the
grid, which provides for dynamic pricing, depending upon the
congestion in the grid. So the coordinator provides for least cost
routing in conjunction with GUIs and web services with the legacy
systems and the settlement processor of the present invention. The
ISO reports the status of the grid to the coordinator, which
determines the optimal financial settlement for grid element
participation. The profiles are further considered by the
coordinator for the grid elements for assessment of grid element
participation location, timing, and combinations, for the supply
and/or consumption of energy from the grid with respect to optimal
pricing for that grid element.
[0075] The present invention also facilitates the ability to bid,
clear, and settle in more locations and by new methods than those
in current art. Legacy grid operations and EMS are in communication
with the coordinator; SCADA control, distribution automation,
transmission reporting, OASIS, and other legacy systems for grid
operations and settlement. According to the present invention, the
coordinator monitors capacity, position and/or location of grid
elements, state of grid elements, their operational purpose on the
electric grid, supply pricing and quantity bids by grid elements
registered with the coordinator to participate in supplying and/or
consuming power from the grid, wherein load curtailment is also
offerable as supply by those grid elements, and considered for
settlement based upon market price as set forth hereinabove. The
price per kilowatt packet, which includes kilowatt hour(s), PSV,
PTB, grid stability information, and combinations thereof, is
communicated between the coordinator and grid elements, and those
grid elements participating in the market pricing acceptance, such
as PJM.
[0076] When a grid element is introduced to the electric power
grid, the grid element communicates to the grid network, via
standards-based or proprietary protocol, through a plurality of
communications methods whether they be wired or wireless, its
necessary information to be incorporated and function as designed
or intended on the electric power grid. The grid element registers
through a coordinator, preferably, after which the coordinator
tracks the grid element and its participation in the electric power
grid. The information relating to the participation of the grid
element is also communicated to the legacy or operational grid
systems, as well as the financial sub-system(s), which receives the
information about the function and participation of the grid
element, registers the grid element for settlement-based (or
financial) participation in the grid; preferably this information
is network-based communication through the coordinator and/or the
translator, according to embodiments of the present invention. The
financial sub-system updates the market, preferably via
communication to the market participant or utility, the grid
element, and coordinator. A customer identifier, a billing
identifier, a grid element unique identifier, and combinations
thereof are assigned to the grid element. Importantly, the grid
element is registered for participation in the electric power grid
as a supplier and/or consumer of electric power from the grid.
[0077] A profile is provided or created for the grid element, by
the market participant, utility, etc., by the owner of the grid
element, and combinations thereof. Preferably, various parameters,
inclusive of market pricing conditions via a customer profile that
can be loaded via a smart phone, tablet, or any web-enabled
appliance for accepting or modifying a profile or moreover a
profile that automated controls based upon previously selected
economic messages.
[0078] An attachment model is created depending upon the function
and purpose of the grid element's participation and provided by the
grid element to the utility, grid operator, ISO, market
participant, and combinations, with that communication also being
IP-based messaging through the coordinator via a communications
network. Preferably, encrypted IP-based messaging is used for grid
element communications. Settlement for a grid element is preferably
less than about 15 minute intervals for supply, curtailment as
supply, and consumption of electric power, and includes the grid
element geodetic location at the time of the grid element
participation. Improved settlement provides for communication with
the financial sub-system, the market, the ISO, the market
participant, utility, and combinations, all via web-based
communications. The financial sub-system serves as a clearinghouse
for the grid element(s), and functions as a point of sale for
electricity to the electric power grid. Additionally, active grid
element profiles for power consumption are included in the present
invention. The embodiments described utilize concepts disclosed in
published patent application US 2009/0062970, entitled "System and
Method for Active Power Load Management" which is incorporated by
reference in its entirety herein. The following paragraphs describe
the Active Management Load System (ALMS), which includes at least
one Active Load Director (ALD), and at least one Active Load Client
(ALC) in sufficient detail to assist the reader in the
understanding of the embodiments described herein. More detailed
description of the ALMS, ALD, and ALC can be found in US
Application Publication 2009/0062970, which is incorporated herein
by reference in its entirety. Generally, the embodiments described
encompass a closed loop system and method for creating a profile,
calculating and deriving patterns of energy usage and/or supply,
and making use of those patterns when implemented through the
machinery of a system comprised of active grid elements combined
with the physical communications link and when these inputs are
manipulated through a computer, processor, memory, routers and
other necessary machines as those who are skilled in the art would
expect to be utilized.
[0079] In another embodiment, energy consumption patterns in active
grid elements profiles are used to identify active grid elements
that are the best targets for excess power sharing or for
supporting grid stability. This would occur when renewable energy
such as solar or wind is added to the grid, resulting in power that
cannot be compensated for by the grid except typically "net
metering" for installations less than 1MW. Under "net metering" a
supplier of solar energy is compensated at the grid element at the
retail rate or a pre-negotiated rate and is not compensated for the
supply of power based upon market conditions or in support of grid
stability. For wind generated power, oversupply conditions could
occur, for example, on very windy days. When this happens,
utilities or market participant, grid operator, EMS, or equivalent
are faced with the problem of what to do with the excess energy.
Instead of cutting power to service points in order to affect power
savings, a utility, market participant, grid operator, EMS, or
equivalent could add energy to service points and through active
grid elements associated with those services points in order to
effect power dissipation. The service points and/or active grid
elements selected by the Coordinator may be different (or even the
inverse) of those selected for power savings. The devices at these
service points would be turned on if they were off or set points
for climate-controlled devices would be adjusted to heat or cool
more than normal. Spread out over many control points, this can
provide the energy dissipation needed. Those grid elements are then
compensated for offering grid stability in the over supply
condition which is recognized in the industry as supplying
regulating reserves for the purpose of grid stability.
[0080] In a further embodiment, energy consumption patterns within
active grid elements profiles could be used to identify
opportunities for up selling, down selling, or cross selling. These
opportunities may be determined by the power utility or by its
partners. Data from active grid elements profiles and their
participation on the electric power grid may be used to provide
insights on inefficient devices, defective devices, or devices that
require updating to meet current standards. Active grid elements
profiles data, and/or data associated with their participation on
the electric power grid, individually or collectively (or
selectively) in the aggregate, may also be used to identify related
power grid participation opportunities.
[0081] Active grid elements profiles and the active grid element
participation on the electric power grid may also be dynamic, and
settlement processing associated with those grid elements includes
consideration of those profiles, in addition to the data from
participation of the grid elements for supply and/or curtailment,
and for energy consumption as well. By way of example, the active
grid elements and their participation within the electric power
grid to utilize real time communications from an electric utility
grid, market, market participant, utility, REP, CSP or any other
entity authorized on behalf of the owner, in combination with the
profiles of the active grid element, to act on their behalf to
control load consuming devices owned by the consumer and connected
to the electric utility grid. Preferably, the active grid elements
receive this information automatically through a plurality of
methods utilizing IP-based communications methods and web based
devices such as smart phones, computers, text messages, paging
messages, or even voice response units or live customer service
agents. Under this real time scenario, active grid elements could
dynamically "Opt In" to a pre-determined profile or "Opt Out" or
more importantly change the profile dynamically to take advantage
of real time market pricing of electricity being sold by the
utility, market participant, REP or any entity authorized to buy,
sell and trade electric commodity or demand response products on
behalf of the owner.
[0082] Transmission and distribution losses are generally modeled
to estimate losses, rather than having actual data, in the prior
art financial settlements for the electric grid; power flow and
power loss models are used due to the lack of availability of
actual data or lack of use of information made available by
actively reporting grid elements. Modeling is usually provided by
the transmission distribution supply (TDSP) and/or utility; they
are given information so that they can calculate (or model) the
transmission losses, rather than use actual data for the losses.
Transmission and distribution loss modeling are used in each feeder
and each electrical bus and substation to approximate losses
between electrical buses, substations and end point where the load
is being served. These are also used when empirical data is
available; they are industry-accepted practices that provide a
level of engineering safety and capacity factors which are widely
accepted practices. Instead of relying only on modeling, the
empirical data are used to correct the models, but it is important
to note that the losses and some grid operations that are affected
by transmission and distribution use modeling for grid operations
and inherently are less effective than the use of real-time and
measured data from actively reporting grid elements where models
are replaced with actual values. All models have coefficients of
loss that may be improved; the modeling is improved for all the
data provided. Transmission loss models are considered for
frequency, distance, size of cable, etc., and combinations
thereof.
[0083] Generation losses are also a function of the efficiency of
transfer, efficiency of transformers, efficiency of resource node,
etc. and combinations thereof. Age of transmission cables,
size/capacity of cables, material utilized in the transmission
line, temperature, insulation, capacitance and reactive power
elements, age of material, type of material, degradation, bending
radius, etc. and combinations thereof are all factors used in
modeling and will also affect the actual empirical measurements or
data. Empirical data is characterizing the distribution environment
so that the modeling is more accurate. Self-correcting algorithms
employed in the model that consider the empirical data can be used
to create closed loop systems that act upon the data without the
need for human intervention. Temperature, humidity, physical
environment factors (e.g., connector/connection, etc.).
[0084] By way of example and not limitation, consider the grid
element as a smart meter, small-scale generation, load curtailment
applications. In the example of small scale generation, or
independent power generation, such as a back-up gas-powered, diesel
or any fossil fueled generator or fuel cell, a resource node is
designated by the grid operator and provided with a revenue grade
meter associated therewith to provide the grid operator with
information about the amount and type of energy or reserve provided
to the electric grid, and a coordinator associated with the grid
element (back-up) supply source. Prior art approximates with
whatever interval data is provided at the resource node and
supplied by the revenue grade meter what each supplier provides on
any given day. Payments in current art are staggered over a typical
30 days interval from each generation day where energy and reserves
are provided to the electric grid. Data from the suppliers are
submitted to the ISO to indicate what was provided but the
teachings in the present invention introduce more dynamic methods
that may increase the accuracy of the settlements provided to each
supplier while decreasing the interval of time required to receive
payment. Payment is provided about 30 days to about 1 year later.
In current art, minimum PTB is about 100 kilowatts to be considered
for a bid for supply to the electric power grid. The present
invention provides metrology grade active load client (ALC), which
is also an active grid element, providing to the EMS through a
coordinator in communication by IP-based messaging over a network,
and then to an active supply director. The grid element supplying
power (generating power for supply to the electric power grid)
provides its output through a TDSP smart meter, collecting
near-real-time information, telemetry, and metrology through the
reading of ANSI or other approved C12.19 tables, communicated to
qualified scheduling entity (QSE) and/or energy registration or
trader that presents the aggregated generation (at least one PTB
unit minimum) and/or operating reserves PTB to the market.
Alternatively, the market supplies information to the coordinator,
which communicates to the ASD, to call immediately or in
near-real-time to generate supply at market prices and to introduce
it to the feeder associated with an electrical bus or substation of
an electric power grid. The coordinator communicates with the
market for obtaining market price at the time of supply, and with
the market participant(s) or utility, NERC/FERC, preferably with
bi-directional communication. The market is always providing
transmission information, price per kilowatt packet, modeling,
forecasting, clearing, schedules, and combinations in real-time or
near-real-time. The ASD and/or coordinator preferably communicate
over a reliable IP-Based network, one-to-many small generation
supply or load curtailment grid elements.
[0085] Market information is supplied from the market through the
coordinator to the grid elements so that profiles associated with
grid elements may be matched, or modified or changed to match, the
market needs at that time. Preferably, each grid element has a
unique grid element identifier, unique grid profile, and further
includes financial account information, for supply or consumption
of power to the electric power grid. The profiles are provided from
the grid elements through the coordinator to the market and/or
market participants. The coordinator also works with the ASD, ALD,
and the legacy systems in a Web Services environment through a
translator, if necessary, to ensure communication between the
operating systems providing electric power throughout the electric
power grid and the financial settlement systems and communications
associated therewith.
[0086] Complex financial pooling agreements are provided to allow
for dispatch capability of calling up resources on stand-by to meet
reserve requirements for a utility, market participant or grid
operator. Forecasting is provided for a generation schedule to each
active supplier of energy and reserves based either upon the
forecasted grid need or based upon market awards based upon bids
submitted to the grid operator, ISO etc. Because of a lack of
real-time information and a lack of modeling accuracy, the grid
operator, market participant, utility, and combinations must
monitor the grid constantly due to the lack of large scale storage
of energy and since supply to the grid, net of grid losses, must
always meet supply plus the Operating Reserve requirement as
specified by the governing entity. Grid transmission and dispatch
(under commercial applications such as OASIS) is observed to
determine the market pricing and availability of transmission
capacity and power (quantity) flows across transmission
intersection points, balancing areas, LMPs or any junction
specified by the governing body; the transmission capacity is made
available to all market participants, whether supply or
generation.
[0087] The present invention provides systems, methods, and
apparatus embodiments for electric power grid and network
registration and financial settlement of participation of grid
elements in supply, curtailment, and/or consumption of power within
the electric power grid. Accordingly, grid elements are transformed
into active grid elements following initial registration of each
grid element with the system, preferably through network-based
communication between the grid elements and a Coordinator. Also
preferably, messaging is managed through a network by a Coordinator
using IP-based messaging for communication with the active grid
elements, with the energy management system (EMS), and with the
utilities, market participants, and/or grid operator's subsystems
necessary for electric grid operations and grid stability.
Following initial registration, the multiplicity of active grid
elements function in the grid through the coordinator and any
associated control systems such as an Active Load Director an
Active Supply Director, an Energy Management System, Master SCADA
system or any new or legacy system utilized for reporting,
telemetry, command & control, status, normal or emergency
electric grid operations in the generation subsystems (of all
generation capacities and types) that supply capacity/energy to the
electric grid, storage devices that supply capacity and energy to
the electric grid and/or load curtailment acting as supply or
capacity (as in FERC 745), wherein the registered, active grid
elements and their corresponding activities and information
associated with those activities are tracked and managed in
accordance with regulations and standards governing the electric
power grid. Furthermore, settlement is provided for activities of
grid elements, namely, financial settlement that corresponds to
participation by each of the grid elements within the electric
power grid, wherein the settlement is preferably provided in
real-time or near-real-time, or less than about 15 minute intervals
or any sub-15 minute settlement increment as determined by the
aforementioned bodies that regulate the activities of the electric
power grid, but within the physical limitations of current grid
element technologies and that contemplate, through this art, the
ability for grid elements to report more frequently to improve grid
stability and to provide efficiencies and cost savings to consumers
of energy, based upon data supplied through the coordinator and
through a translator via network-based communication with the
settlement processor, as illustrated in FIG. 1. Included with the
settlement processor are components for authentication, customer
verification, location, attachments, settlement switch and
associated match service for supply and demand, and clearing price,
operable within a settlement processing engine having rules
illustrated in FIG. 1, and in communication with a database,
connect service for account management and grid element account
portal, including grid element profiles, and further connected with
web APIs and service database, enterprise service bus, and service
data, further including management, historical, and settlement
history data stored in corresponding database(s) or proprietary
custom interfaces necessary for newer grid elements and their
subsystems to interface with older subsystems of control and
settlement of the grid operators or Market Participants. A
translator further connects in network-based communication with the
settlement processor to an accounting engine, utility and/or
financial institution accounts, and customer and/or supplier
accounts for settlement associated with the grid elements and their
owners. The grid elements are physically electrically and
network-based communication connections within distribution feeder
subsystems, including connection to the electric power grid at a
multiplicity of attachment points. The grid elements are further
connected via a coordinator, which is preferably, but not
exclusively, co-resident with the settlement processor, and further
in electrical network-based connection with an acquiring switch, an
acquiring gateway, and then with a resource node and corresponding
resource node processor, which is in network-based communication
connection with the settlement processor, as illustrated in FIG. 1.
Also preferably, the settlement processor communicates with legacy
settlement processor(s) and/or database(s) associated with the
resource node and/or load zone, and the settlement processor
accesses or references the related location-based marginal price
for the grid element participation associated with the resource
node(s) and/or load zone(s) corresponding to the grid attachment
point for that participation and/or activities within the electric
power grid.
[0088] According to the present invention, at least one grid
element of the grid element(s) includes transmission or
distribution control node(s), monitoring node(s), telemetry
node(s), routing node(s), electrical routing node(s), fault
protection node(s), generation node(s), load control node(s),
devices (active & passive), sensors, etc., wherein a node may
further include an interface and/or an attachment to the grid. The
grid operations include functionality that is provided by a
multiplicity of different grid elements associated with supply,
command/control, monitoring, and curtailment activities as separate
activities for active grid elements.
[0089] Overall, the systems and methods, and apparatus of the
present invention provide grid element(s) and their registration
for initializing their functionality within the electric power
grid, wherein the registration transforms the grid element(s) into
active grid element(s) through network-based communication with a
server and/or a processor operatively coupled with a memory. The
functionality of each grid element, following registration and
transformation into active grid element(s), varies according to the
grid element itself and its physical connection to the electric
power grid. In many instances, the active grid elements function to
provide power supply and/or curtailment as power supply, and/or
capacity for same, that provides for grid stability, operating
reserves, and/or other reserves of an electric power grid. However,
in every case, any active grid element registered with the electric
power grid management system must be operable for network-based
communication with the server and/or the processor operatively
coupled with memory. More preferably, grid elements communicate
through a Coordinator via messaging communicated over a network,
wherein the messaging is Internet protocol (IP)-based messaging, or
proprietary communications network protocols and transported by a
plurality of network methods as described hereinbelow.
[0090] Each grid element has a first location within a first
boundary, which is referenced as a home identifier. A corresponding
foreign identifier is used for each grid element with respect to
other entities outside the first boundary, i.e., wherein the grid
element(s) change connection or position with respect to the
electric power grid connection point or node, or the grid
element(s) are also identified with a second location at another
point in time relating to settlement. For the case of movement or
change in connection or position for each grid element(s), the
corresponding unique grid identifier changes to reflect the
location change, and the rules governing settlement for the grid
element change with respect to function, timing, location,
boundary, etc., as well as changes in security. The present
invention further provides for a home location register wherein at
that point in time within the boundary the grid element is an
active grid element that is registered to participate in the
electric power grid by supply and/or curtailment. Correspondingly,
a visitor location register is provided and associated with the
second location of the grid element(s).
[0091] The present invention further includes messaging to mobile
device(s) and/or remote computer devices or processors relating to
activation or deactivation of any grid elements registered and
associated with communications through that mobile device, and for
settlement information to be including with the messaging of grid
element(s) participation within the electric power grid. By way of
example and not limitation, the systems and methods of the present
invention provide for automated messaging to the grid element
owner(s) regarding the most efficient settlement zone and/or
attachment point for the grid element and communication of
information for mobile settlements. A maintenance port is provided
within each IR reader for changing the billing plan and retail
electric provider instantly if the message is not transformed thru
the existing mobile device. If sharing databases or persistence
layers, then messaging makes automatic modifications to billing
system, etc. Included with the systems and methods of the present
invention are the context of relevant boundaries (or zones) to
determine how to define and invite new participants automatically
based upon profiles and location and registration attributes.
[0092] Claimed Invention Description
[0093] The present invention systems and methods for settlement of
transactions within an electric power grid network include: a
settlement processor, comprising a server and/or a processor
operatively coupled with a memory, database, constructed and
configured for electrical connection and network-based
communication via a network with at least one coordinator, wherein
each of the coordinator(s) is constructed and configured for
electrical connection and network-based communication with at least
one active grid element that is registered to participate within
the electric power grid.
[0094] The present invention systems and methods further include a
translator constructed and configured in network-based
communication with the coordinator and with at least one legacy
system for financial settlement processing. Note that settlement
for participation in the electric power grid for supply,
curtailment as supply, and/or consumption or usage of power
(demand) includes electric utility power settlement, alternative
energy settlement or credits, including but not limited to carbon
credits, and combinations for at least one power trading block
(PTB) unit within or across any boundary, balancing authority, grid
operator or market. The financial settlement is provided in at
least one currency, and preferably is provided in an electronic
financial settlement or digital financial settlement, which does
not require physical currency exchange between participants in the
electric grid.
[0095] In preferred embodiments, the settlement processor operates
to provide an automatic and/or autonomous financial settlement for
each of the active grid elements based upon their participation
within the electric power grid. Furthermore, the settlement
processor provides a financial settlement based upon a kilowatt
packet (KWP) unit, a power supply value (PSV) unit, a power trading
block (PTB) unit, and combinations thereof. A KWP is one or less
kilowatt hours units, or any government, regulatory, or governing
entity for an electric power grid accepted method for quantifying
rate for monetization for any unit of kilowatts with respect to
time. Thus, the financial settlement of the present invention is
optimized for each KWP, PSV, PTB, and combinations for each grid
element that participates in the electric power grid (in any way).
The present invention provides settlements that are currency and/or
commodity agnostic, i.e., the settlement is not restricted to a
single currency or commodity. The present invention systems and
methods provide any improvement in settlement from the initial
settlement where the participation in the electric power grid is
financially compensated in either direction (supply or demand)
including but not limited to: improved data, improved accuracy,
improved analytics relating to grid element participation, and
combinations thereof. These improvements reduce the amount of
uncertainty associated with losses, lack of data, gaps in data,
etc. with respect to the electric power grid and grid element
participation thereon and financial settlement therefor. Notably,
aggregation analytics ensure optimized settlement for each grid
element, including consideration of boundaries, timing, attributes,
etc. The effect is that electric power flows through the grid are
considered equal irrespective of source, so long as the supply
meets regulatory requirements associated with the functioning of
the grid. This provides for essentially functioning cooperatives of
grid elements that are not retail electric providers, but have the
net effect of and/or function virtually as retail electric
providers, because their aggregation, analytics, combination,
integration, and combinations thereof allow them to function and to
receive compensation as if they are macro generation, due to
increased data sampling and/or accuracy within predetermined
locations that is different from other geodetic locations due to
the spreading effect that is greater at the first location. So then
because the data provided by the systems and methods of the present
invention are more accurate and better than anyone else within the
boundary or settlement zone on that day, grid elements and their
owners using these systems and methods will always receive the best
compensation for their participation in the grid at that time.
Additionally, the systems and methods provide for connecting or
forming of aggregation blocks that are boundary independent and
that are contrary to the existing geodetic boundary for providing a
virtual utility zone with the aggregated PTBs. The creation of the
PTBs and power supplied by multiplicity of grid elements has its
own carbon footprint and corresponding carbon credits, so then
alternative energy credits, offsets, or other form of settlement
may also be aggregated, including carbon credits, NOx, sulfur
reduction, are effectively aggregated into alternative energy
credits as PTBs. The present invention provides for grid elements
to have virtual settlement points (or attachment points) and/or
virtual PTB groupings. Thus, virtual grid element settlement points
provide a substitution for physical boundary-based settlements.
[0096] By way of improvement over the prior art, the settlement of
the present invention is processed by the settlement processor in a
predetermined timeframe associated with reporting frequency
associated with the participation of grid element(s) within the
electric power grid, wherein the day of participation is considered
day zero (0); data relating to the participation for those grid
elements is more accurate than any other because the data
gathering, modeling, sampling, and combinations are made at less
than 15 minute intervals.
[0097] The at least one coordinator is remotely positioned from the
settlement processor, and the participation of the grid element is
communicated to the coordinator via the network. Preferably, the
participation of the grid element is automatically and/or
dynamically communicated to the coordinator via the network,
preferably in real-time or in a predetermined timeframe, and the
network-based communication is a standards-based communication or a
proprietary communication, and more preferably includes IP-based
communication that is routable through a router and/or through a
coordinator.
[0098] Within the electric power grid or any sub-grid level, a
multiplicity of grid elements aggregate and/or integrate through a
master or aggregator grid element and/or a virtual grid element
that represents the participation of the multiplicity of grid
elements as one grid element, i.e., digital cross-connection
wherein the master grid element is over the other grid elements
associated with it. Thus, following registration with the system,
each of the multiplicity of grid elements, upon aggregation or
integration, and association with the master grid element,
transform into sub-grid elements, wherein the sub-grid elements
have corresponding financial settlements that are unique and
correspond to each of the sub-grid elements, and wherein a
financial settlement is unique to each sub-grid element, and
furthermore, is unique to the location and function of each
sub-grid element for its participation in the electric grid. The
unique financial settlement for each sub-grid element further
includes coordination with at least one virtual ID and/or smart
meter. Furthermore, each of the grid element(s) is a device that
provides any power that is monetized and recognized by a governing
entity associated with the electric power grid.
[0099] In the case where at least one of the at least one grid
elements is a control device, the control device operates,
programs, and/or updates the power-consuming device. The grid
element(s) may be selected from the group consisting of: a sensor,
a power-consuming device, an appliance, a meter, a switch, a
controller, a control device, a power control subsystem integrated
with grid element for supply, a thermostat, a building control
system, a security device, any electrical device, and combinations
thereof. At least one of the grid elements is under the control of
an energy management system (EMS) and/or SCADA system. In any case,
preferably each grid element includes telemetry, wherein the
telemetry follows industry standard for EMS and/or SCADA
control.
[0100] According to the present invention the transformation
relating to the active grid element enables the active grid element
to provide operating reserves and/or grid stabilization for the
electric power grid. The grid elements transform into a
corresponding plurality of active grid elements after initial
connection with the server via the network. The grid element(s)
is/are an electrical device that provides or consumes electric
power from an electric power grid, wherein the supplied power is
reactive power, voltage support, supplied power for operation, and
combinations thereof. Data is transformed at the grid element
level, or at the sub-meter level, based upon location with the
grid, the function it performs with respect to the participation in
the grid, monetizable equivalence (which may be paid for settlement
differently in different ISOs, e.g., ERCOT for emergency
interruptible load service, PJM for interruptible load reserves,
wherein the timing is different. Attributes and/or profiles for
each of the activated, registered grid elements are associated with
each grid element after its transformation. Preferably, each of the
at least one grid elements has a unique grid element identifier,
which includes at least one of an unique customer identifier or a
tax identifier. An unique grid element identifier includes an IP
address, equipment identifier, mac address, or combinations
thereof. Preferably, the unique grid element identifier further
includes location-based factors, such as Google Earth, ray tracing
for geodetic locations, physical mapping and combinations thereof,
time-based factors, grid-function-based factors, and combinations
thereof.
[0101] In one embodiment of the present invention, the server
initiates the financial settlement of the participation of the at
least one grid element, and the financial settlement of the
participation of the at least one grid element is stored in a
database or any data storage such as ASIC chips, wherein the data
is persisted at the grid element, accessed from memory registers,
transformed, and communicated or transmitted to the server through
the network and preferably via the coordinator, wherein the
database is registered with an ISO, BA, control area, utility
service area, any geodetic junction where settlements are performed
as determined by the governing entity, and/or FERC. Settlement of
the present invention is preferably associated at or proximal to
the grid element location and/or the participation of the grid
element within the grid, and the financial settlement is a function
of load or supply.
[0102] A multiplicity of databases that are constructed and
configured in network-based communication for receiving settlement
data from a multiplicity of grid elements may be provided, wherein
the databases may be cross-linked or associated in network
communication, and may further include internal tables with rows,
columns, and values; the server may extract, transform, and
replicate data across the databases. As will be appreciated to one
of ordinary skill in the art, the databases include at least one
production database, and connection layers in at least two parts,
further including middleware that connects multiple applications to
databases (APIs that are SOA-based), and that allow native
applications to send info in SIMM format to allow connection to
databases, messaging engine(s) that may interact with a cache or
persistence layer, and applications that sit on top of it, as well
as firewalls and other physical security, encryption layers, and
combinations. Encryption may be direct networked, cloud-based,
IP-based or Ethernet-based network encryption.
[0103] The at least one coordinator provides for routing messages
from the multiplicity of grid elements through the network
connecting the databases, and wherein servers operating the
databases exchange information associated with the grid elements
for affecting grid stabilization.
[0104] Each grid element is registered with the system and wherein
the registration of grid elements is stored in the databases for
predetermined periods of time for use with a financial settlement
associated with the grid elements, and the information relating to
financial settlement of the participation of the at least one grid
element is stored in a database, and any raw measurement data is
transformed into settled measurements for storage in a database.
Furthermore, the information relating to grid elements
participation is transformed from raw data into settlement data,
and wherein the settlement data is stored in a database.
Preferably, a web-based graphic user interface (GUI) display
operates to communicate information to the grid operator(s) via
encrypted IP-based communication. Raw measurements are not required
to be retained in the database(s); however, transformation methods
are retained and transformed settled data are retained; such that
if market rules change, then the system and methods of the present
invention provide for optimized settlement based upon updating the
settled data to reflect latest rules. Thus the analytics engine(s)
provides for reversible, updatable data from raw to settled, and
then updated settled, to improve the settlement financial amount to
compensate the participation of the grid element(s) within the
electric power grid at the optimal rates for that period of time
for the participation. Overall, the present invention provides for
better, more accurate settlements in any format, including
traditional currency or commodity trading or valuation, bartering
KWP in PTB unit(s) in exchange for non-currency remuneration,
credits, and combinations thereof.
[0105] The registration information associated with grid elements
is used to determine attachment points to the electric power grid
for distribution and transmission of power, and wherein the
attachment point information associated with the grid elements is
communicated to the settlement processor.
[0106] The settlement information associated with grid elements is
preferably further communicated to or accessible by the market
participant, utility, grid operator, etc., wherein a settlement is
made for each grid element, and the settlement complies with
regulations and/or standards established by FERC, NERC, and/or a
governing authority for the electric power grid.
[0107] The server communicates a settlement message to each of the
at least one grid elements via the network, wherein the settlement
message is preferably an IP-based message. The grid element
participation in the grid is provided for use by market
participants via a display through a web-services enabled GUI. It
may be accessible to and/or communicated via the network to payer
and payee, trader, consumer, resource provider, TDSP, and/or market
participant or entity who would benefit from having the capacity to
monitor settlements including but not limited to ISO, RTO, etc.,
which need visibility to clearing price, and to financial
settlements for grid element participation. Empirical data of the
present invention associated with each grid element, because of its
actual data collection over less than 15 minute intervals, has more
granularity than modeling used in the prior art, so that the
present invention systems and methods provide higher accuracy
information that is relevant to making market-timing decisions and
actions relating to participation by grid elements and owners
thereof. For example and by way of comparison, this is not unlike
futures trading in the markets, which requires visibility into
clearing price. The exchange of information and its display and
representation of data for advanced and automated settlements is
preferably associated with kilowatt packets, PSVs, and PTBs.
Real-time access for trading and for participation in the grid by
grid elements is improved. Speed and security of data, in addition
to increased accuracy and increased timeliness of data provided and
communicated within the systems and methods of the present
invention provide for improved financial settlements for
participants. Empirical data has more granularity than modeling
used in the prior art, the present invention provides higher
accuracy information that is relevant to making market-timing
decisions and actions relating to participation by grid elements
and owners thereof, for example and by way of comparison like
futures trading in the markets, which requires visibility into
clearing price.
[0108] This settlement message associated with the grid element
participation is transmitted either wired or wirelessly by grid
elements, and includes an interface that facilitates communication
of the settlement message with the grid elements, such as an
interface that includes an IP-based interface. An IP-based
interface is preferably selected from the group consisting
essentially of WiMax, High Speed Packet Access (HSPA), Evolution
for Data Only (EVDO), Long Term Evolution (LTE), any first or
second generation wireless transport method such as EDGE, or Code
Division Multiple Access, Ethernet, any proprietary Layer 1-4
protocol that contains or is capable of transporting an Internet
Protocol message, and combinations thereof. Preferably, the
settlement message includes a derived Power Supply Value that meets
the minimum requirements for measurement, verification and
reporting accuracy as determined by the Governing Entity that
regulates the operation of the electric power grid that includes
utilities, market participants and/or grid operators.
[0109] Also, the systems and methods of the present invention
include a security interface associated with each of the grid
elements operable to receive security system messages from at least
one remotely-located security system, wherein the security
interface is standards-based or determined by the governing entity
that regulates grid operations for utilities, market participants
or grid operators.
[0110] The settlement message may further include a delivery
priority including at least one of a plurality of methods to
include priority access flags, virtual private networks,
independent identifying addresses (MAC, IP, Electronic Serial
Numbers), manufacturers specific identifying codes, or combinations
thereof, wherein the methods comply with standards as determined by
the governing entity that regulates grid operations for utilities,
market participants or grid operators. There may be dedicated
routes, private networks that are Ethernet or proprietary, or other
prioritized packet or encryption formats that have been created or
approved for settlements by the governing body and/or standards
bodies.
[0111] The grid element(s) further include at least one mobile
device having at least one access point name (APN) for providing a
priority of delivery for the message, wherein the at least one grid
element transmits a signal or communicates a message to the server
at the point of initial connection with the server via the network.
Thus, the system may initiate the settlement request based upon
disconnection, etc., or a customer or owner of any grid element
(user) may initiate the settlement based upon user-inputs (from a
mobile device, a computer, etc.) or by any profile change for any
grid element.
[0112] The grid elements communicate a signal or a settlement
message to initiate a financial settlement corresponding to
participation in the electric power grid, and the signal or the
settlement message is routed through a coordinator, which routes
the settlement message to the settlement processor.
[0113] The settlement message further includes at least one of: a
geodetic reference, a element identifier, a grid element type, a
grid element function, a grid element capacity, a grid element
profile, a grid element attachment point reference, a kilowatt
packet (KWP) value, a grid element power supply value (PSV), a grid
element power trade block (PTB) value, a grid element balancing
authority association, a grid element owner identifier, a grid
element compatibility identifier, and combinations thereof.
[0114] The financial settlement of the present invention includes
factors for grid stability-based pricing, operating reserves-based
pricing, factors considering peak and off-peak timing, and
combinations thereof, and further include measured data that
provides higher rate for settlement compared with projected,
estimated, or VEE rate, and includes variable, higher, and more
accurate rate for settlement, compared with projected or VEE. Thus
the coordinator and/or server with information from the coordinator
transforms the raw data from grid element participation in the grid
into more accurate settlement data, which is then compensated at
the optimal rate for that participation for that given time period.
Preferably, the financial settlement is managed by a clearinghouse
between market participants and utilities, and may further include
individual cooperatives, groups (non-traditional), and non-boundary
constrained groups, cooperatives that function to aggregate groups,
etc.
[0115] Preferably, upon registration with the grid, each of the
grid elements have a home location identifier and a non-home
location identifier, and wherein the financial settlement includes
factors and attributes for grid element participation associated
with the home location identifier and with the non-home location
identifier, which may further include factors associated with
boundaries, regulations associated with each of the boundaries
including factors affecting settlement across boundaries, within
boundaries, etc., and considers the participation of the grid
elements based upon location, and rules governing their Market
participation.
DETAILED DESCRIPTION OF THE FIGURES
[0116] As illustrated by FIG. 1, a settlement processor is provided
for systems and methods of the present invention. Advantageously,
and by way of comparison to electronic settlement associated with
point of sale transactions, for example as with gasoline purchases
at a pump station with electronic payment, traditional boundaries
used with financial settlements for grid elements are not
restrictive factors with the systems and methods of the present
invention. By way of illustration and not limitation, a grid
element may be an electric vehicle; once registered through the
coordinator to participate in the system, the mobility of the grid
element allows it to connect and participate within the power grid
to consume or draw power (charging) and to supply power
(discharging the battery) at a multiplicity of locations across
traditional boundaries. With the systems and methods of the present
invention, the grid element location for its participation
(consuming or supplying power) is automatically identified with the
activities and the settlement for that participation is provided at
the point of attachment.
[0117] Referring now to FIG. 2, a schematic diagram illustrating a
virtualized computing network used in of one embodiment of the
invention for automated systems and methods is shown. As
illustrated, components of the systems and methods include the
following components and sub-components, all constructed and
configured for network-based communication, and further including
data processing and storage. As illustrated in FIG. 2, a basic
schematic of some of the key components of a financial settlement
system according to the present invention are shown. The system 200
comprises a server 210 with a processing unit 211. The server 210
is constructed, configured and coupled to enable communication over
a network 250. The server provides for user interconnection with
the server over the network using a personal computer (PC) 240
positioned remotely from the server. Furthermore, the system is
operable for a multiplicity of remote personal computers or
terminals 260, 270. For example, a client/server architecture is
shown. Alternatively, a user may interconnect through the network
250 using a user device such as a personal digital assistant (PDA),
mobile communication device, such as by way of example and not
limitation, a mobile phone, a cell phone, smart phone, laptop
computer, netbook, a terminal, or any other computing device
suitable for network connection. Also, alternative architectures
may be used instead of the client/server architecture. For example,
a PC network, or other suitable architecture may be used. The
network 250 may be the Internet, an intranet, or any other network
suitable for searching, obtaining, and/or using information and/or
communications. The system of the present invention further
includes an operating system 212 installed and running on the
server 210, enabling server 210 to communicate through network 250
with the remote, distributed user devices. The operating system may
be any operating system known in the art that is suitable for
network communication as described hereinbelow.
[0118] The present invention further provides systems and methods
for settlement of participation in the electric power grid by grid
elements that include a coordinator and/or translator network-based
communication to communicate with legacy systems associated with
the electric power grid, the legacy systems including network
management systems, energy management systems, ISO, utility, SCADA,
EMS, meter data, tables, graphical information system asset
management server including updated changes within the distribution
system, customer information systems, enterprise billing systems,
outage management systems, data warehouse, historical data, legacy
demand-side management system, legacy information and/or control
system having grid information for grid elements for active control
of those grid elements, and combinations thereof. Regardless of
type and frequency of telemetry for those legacy systems, the
present invention provides for increased frequency up to real-time
data, and improved accuracy of data associated with the
participation of the grid elements in the electric power grid.
Benefits for the consumer of electric power from the grid include
more accurate data associated with grid element participation in
the grid, and therefore reduced payments and/or increased total
compensation in the case of a power generator or curtailment
activities acting as supply.
[0119] For the present invention, a node is a point within the
electric power grid at which power is generated or drawn out.
Resource nodes are the points at which power is passed back,
connectivity nodes of the generator to the system. Settlement
quality measurement of the injections and withdrawals; 15 min price
is calculated and used for real-time energy settlement through the
use of reporting grid elements that possess revenue grade
metrology, as defined by standards bodies, such as ANSI in North
America, or the appropriate standards bodies that specify the
accuracy to classified as revenue grade by the governing body and
are transformable by changes in the software and or firmware to
improve the accuracy of the power measurement at the point of
settlement. Thus the systems and methods of the present invention
provide for accuracy improvements of any type, and any and all
updates to profiles, preferences, and any other upgrade associated
with any grid element, in particular those providing for increased
settlement accuracy, which are communicated over the network by
IP-based messaging or proprietary messaging.
[0120] The ratings of the GSU are provided by the resource entity
and are entered into the model. The 15 min price is calculated for
the resource node, even if the resource node is offline. A clearing
price is still calculated, even if no additional power is supplied
by a generator at that node and also, for the resource node, in the
event transformers de-energize for maintenance. Grid elements are
deployed and are configurable in a loop (or a loop feeder) fault
tolerant design so that if there is a fault, the power is re-routed
automatically. The 15 minute-based prices can change and be
recalculated in the event that part or all of the electrical busis
de-energized. Some feeders off of electrical buses are not in a
fault tolerant configuration and when they fail or are
de-energized, it is still possible to clear a price for providing
resource if a supply or curtailment source has been registered
through the art and ultimately to the grid operator, Market
Participant, ISO, utility, or plurality thereof. In this use case a
distributed energy resource can inject energy to the de-energized
distribution or transmission lines and thus create the use case of
settlements per attachment or per measuring grid element per
customer. Nodal price is equal to the subsystem average in the
prior art; this teaches away from the present invention inasmuch as
the systems and methods of the present invention provide for
real-time accurate measured contributions and load consumption.
Thus, price for generation is optimized and/or maximized for each
grid element that participates in supply of power or load
curtailment as supply to the grid at those nodes. Clearing price
for power is provided at the node, in the example case wherein the
electrical bus is de-energized and alternative and/or distributed
power supply is provided to any and/or all of the power-consuming
grid elements associated with that node, includes not only the
capacity and energy charges, but also preferably includes the base
distribution and attachment charges, which are normally granted to
the TDSP for that period of time in which such power is supplied,
measured, tracked, communicated, transformed, etc. according to the
present invention for settlement.
[0121] Preferably, systems and methods of the present invention
consider the information provided by ISO, which publishes a day
ahead, a week ahead, a month ahead and/or real time pricing for
capacity, energy and operating reserves. Consideration of this
information provide by ISO is provided through a pricing element
communicated through the Coordinator. The pricing element may
further include factors and/or information relating to the impact
of commodity pricing (e.g., natural gas) as an input to the
settlement systems and methods of the present invention.
[0122] A resource node is associated with the electrical bus, in
which a resource is measured and an output is settled. It is
theoretically possible to settle at the electric bus for generation
resource connected to the grid at only one electric bus, then at
that bus as the resource node. For all others, the resource node is
the generation resources side of the e-bus where the generation
source is connected to the electrical power grid or where there are
aforementioned boundaries that also possess a grid element that
employs revenue grade metrology and reporting thereof.
[0123] Settlement for grid elements according to the present
invention considers the location of each of the grid elements, the
location settlement at the closest node for the connection of the
grid element(s) to the electric power grid, including the physical
attachment point to the distribution system or at the grid element
that measures the "net" power injected at the attachment point to
the electric grid that is also capable of grid stabilization
(frequency synch, voltage support, etc.).
[0124] As set forth hereinabove, the prior art includes estimations
and network models that are used to approximate the electric power
flows in the grid, particularly the transmission, distribution
system and losses at or approximate to the attachment points of
loads; however, the present invention includes estimations, network
models, and, significantly, real-time measurement of actual
participation by each of the grid elements, and the losses
associated with transmission, distribution, and resource nodes,
versus estimations. By way of example and not limitation, the
present invention provides for kilowatt packet based settlement,
including power supply value (PSV) factors and, where appropriate
or required, including aggregation of supply and/or load
curtailment as supply activities by a multiplicity of grid elements
and/or entities to provide a power trading block (PTB) or minimum
amount required for settlement. Thus, the estimations and
approximations are replaced with actual data captured under the
present invention systems and methods; therefore the efficiency of
the electrical power grid settlement and functionality, because
increased capacity so that additional resources utilize existing
infrastructure to its fullest extent without incurring redesign or
new construction to expand capacity of the grid distribution and
transmission. Furthermore, because the new art contains an active
coordinator which when in combination with processing and database
elements allow for the decision making and ultimately pricing and
resource nodes to be defined further down in the distribution
system and closest to the end consumer, ultimately improving the
operations and efficiency of the grid, maximizing transmission and
distribution capacity and most importantly saving the consumer
money or its equivalents for compensation. It also facilitates the
participation of the same consumers who possess distributed energy
or curtailment technologies to participate in the market and
respond to market pricing conditions to improve the supply and grid
stability.
[0125] By contrast to the prior art, embodiments of the present
invention preferably provide for real-time data to be used to
inject grid elements that further improve grid operations and
functionality for distribution of electric power in the grid.
Clearing and monetizing the increased capacity is another benefit
of the present invention systems and methods, which provides that
increased capacity is measured and settled.
[0126] In one embodiment of the present invention, metering for
settlements and billing is preferably provided with the advanced
communications via network, preferably IP-based communication for
grid elements through the coordinator to allow participation in the
electric power grid by grid elements for supplying, providing
curtailment as supply, and/or consuming power or usage and
financial settlement that allows customers to provide supply,
curtailment as supply, and/or consume power beyond their committed
base rate or anticipated rate in response to requirements of the
grid (for increased supply, for grid stability, etc.) that are
communicated or projected by EMS. This allows the grid operator
and/or market participant with the ability to activate supply from
any source and provide for financial settlement therefor including
consideration for the cost of the infrastructure and transit
commits, if any, capacity, grid stability, and combinations
thereof. This provides an alternative to either capped ports with
fixed billing or actual data transferred, which are models more
frequently seen in the prior art electric grid settlements, where
occasional usage "bursting" is either not allowed or penalized with
higher bills, either of which penalizes the customers. In preferred
embodiments of the present invention, systems and methods provide
for advanced financial settlements for grid element participation,
including data communication through the coordinator and/or
translator to interact with legacy systems, as needed, and to
interact with the grid elements and/or their controlling owner
through network-based IP communication of actual participation with
supply, curtailment as supply, and/or consumption or usage of power
(demand), wherein the data rate sampling of activity for
participation and corresponding settlements are provided on a
less-than-15-minute interval, preferably less than 10 minutes, and
more preferably less than 5 minutes. Exemplary data sampling
techniques are provided in unrelated art, such as for 95.sup.th
percentile metering, with such techniques as set forth in the
article entitled "95.sup.th percentile bandwidth metering explained
and analyzed," (written by Dylan Vanderhoof, dated Apr. 4, 2011)
for datacenter bandwidth metering as described in the article being
incorporated herein by reference in its entirety.
[0127] By contrast to the settlement systems and methods of the
present invention, OASIS is an example of prior art that reserves
capacity on transmission subsystems at boundaries where
transmission control between two grid operators intersect. OASIS
"tags" transmission capacity at these boundaries; only providing
that information at boundaries, notably because the utility or grid
operator may own or control the lines within the boundaries. New
developments in the FERC regulated transmission subsystems allowing
for the private ownership of transmission lines that also regulated
by tariff and by FERC also must present capacity information to
industry accepted market information subsystems at the boundaries.
Without actual loss information as present art provides, the
likelihood that consumers (loads) are overpaying for inefficiencies
of the "wires" can reach as high as 50% in some estimates of the
industry. If the information and transformation of grid elements
provided by the described art provides more capacity for the
"wires" utility or grid operator, the transmission distribution
service provider (TDSP) can sell more electricity at higher rates
if real-time measured data is available and used for settlement,
rather than merely extending to all consumers, as a percentage
and/or flat fee charge in addition to usage-based, rate-based
charges. There is otherwise no incentive for utilities/TDSPs who
are rate-based to improve the efficiency of the electric grid for
distribution and transmission within their boundaries. The present
art teaches away from legacy methods by necessity. Without the
present art, long term costs of power for end-consumers will
dramatically increase as world-wide power consumption is projected
to double in the next 20 years while capacity within the networks
of most utilities is not being replaced and new transmission
subsystems are not keeping pace with demand. Public Policy and FERC
have recognized these facts hence the issuance of the
aforementioned FERC orders, with more to come, and projections from
the NERC Long Term Reliability Assessment report projecting
capacity margins declining in most RTOs, utility service areas and
other geodetic references.
[0128] The coordinator within the systems and methods of the
present invention provides for settlement for grid element(s)
participation in the electric power grid by energy and
communications routing through and with the existing settlement
infrastructure for the electric power grid. The systems and methods
further include at least one translator or converter to work within
the legacy systems, ISO, market participants, etc. for the electric
power grid for importing and exporting data and information
relating to settlement. This data is integrated automatically by
the systems and methods of the present invention at the translator
or converter so that the data associated with the grid element(s)
participation in supply or demand curtailment as supply, or load
(power consumption), and translate the data for use in automated
real-time settlement. Preferably, the automated real-time
settlement includes actual, measured data for each of the grid
elements, transformed into kilowatt packet (KWP) units. Also,
preferably, KWPs are further combined with power supply value
(PSV), and aggregated to form a minimum power trading block (PTB),
and combinations, as required for optimized and maximized
settlement values for load and for generation, respectively, i.e.,
power consumers are charged accurately for actual power consumed,
and generation supply providers are paid maximally for their
participation (availability for supply and/or actual supply), due
to the improved data accuracy, and improved data availability (more
data and/or continuous data supply, or anything improved over the
standard, which is about 15 minute intervals). Preferably,
financial settlement for each of the grid elements is provided by
systems and methods of the present invention for participation by
grid elements in real-time or less than 15 minute interval
data-time.
[0129] Grid Elements Registration & Communication
[0130] The present invention provides a system for electric power
grid element and network management including: at least one grid
element constructed and configured for electrical connection and
network-based communication with a server and/or a processor
operatively coupled with a memory; wherein the grid element is
transformed into at least one active grid element after initial
connection with the server and/or the processor operatively coupled
with the memory via a network. Preferably, the transformation for
grid elements is automatic and/or autonomous. In one embodiment of
the present invention, the server and/or processor coupled with
memory initiates the transformation of the at least one grid
element into the active grid element. In another case, the at least
one grid element transmits a signal or communicates a message to
the server at the point of initial connection with the server via
the network, and/or the at least one grid element communicates a
signal or a message to initiate its transformation via registration
with the electric power grid; preferably, the signal or the message
is routed through a Coordinator, which routes the message to a grid
operator's appropriate subsystem depending on the function of the
grid element. For grid stability, supply, and curtailment
technologies functioning as supply as contemplated by FERC Order
745 the message must be routed to an EMS. Also, preferably, the
message further includes at least one of: a geodetic reference, a
grid element identifier, a grid element type, a grid element
function, a grid element capacity and or energy capability, a grid
element profile, a grid element attachment point reference, grid
element telemetry capabilities and requirements based upon its
function, a grid element power supply value (PSV), a grid element
power trade block (PTB) value, a grid element balancing authority
association, a grid element owner identifier, a grid element
compatibility identifier, and combinations thereof.
[0131] Also preferably, the network-based communication is a
standards-based communication or a proprietary communications
protocol, and the communication is routable through a router and/or
through a Coordinator, wherein the Coordinator receives and sends
messages through a communications router. A translator is
preferably further associated with the settlement processor and/or
coordinator(s), for example, but not limited to the illustration of
FIG. 1. The message includes a derived Power Supply Value that
meets the minimum requirements for measurement, verification and
reporting accuracy as determined by the Governing Entity that
regulates the operation of the electric power grid that includes
utilities, market participants and/or grid operators such that the
derived PSV may be settled in the appropriate power market by a
settlement manager or appropriate market participant or entity
determining economic benefits associated with the provision of
supply and/or curtailment by the active grid elements registered
and functional within the electric power grid and responsive to the
needs and requirements of the grid. Also, the message has a deliver
priority including at least one of a plurality of methods to
include priority access flags, virtual private networks,
independent identifying addresses (MAC, IP, Electronic Serial
Numbers), manufacturers specific identifying codes, or combinations
thereof, wherein the methods comply with standards as determined by
the governing entity that regulates grid operations for utilities,
market participants or grid operators. Also, the active grid
element(s) may further include at least one mobile or network
device having at least one access point name (APN) for providing a
priority of delivery for the message.
[0132] The present invention provides for a plurality of grid
elements that transform into a corresponding plurality of active
grid elements after initial connection with the server via the
network, and the at least one grid element includes at least one
electrical device, a device that consumes electric power from an
electric power grid, and/or a device that provides power to an
electric power grid, a control device, that operates, programs,
and/or updates other active grid elements. Active grid elements are
eligible to participate in settlement-related activities, as
illustrated in FIG. 1, and described hereinabove. Thus, grid
elements are also selected from the group consisting of: a sensor,
a transmission reporting or control device, a distribution system
reporting or control device, a power-consuming device, an
appliance, any inductive device that consumes power, any resistive
device that consumes power, a meter (revenue grade or non-revenue
grade), a switch, a controller, a control device, a thermostat, a
building control system, a security device, any other distribution
automation and elements that are part of distribution system such
as transformers, traditional and solid state bi-directional,
capacitor banks, reclosers, and combinations thereof. Also, at
least one of the grid elements is under the control of an energy
management system (EMS) associated with the electric power grid.
Preferably, systems and methods of the present invention provide
for micro-economic dispatch capabilities, including
sub-micro-economic dispatch, and settlement therefor, which provide
for security of grid operations and corresponding settlement for
grid element participation in response to information provided by
ISOs relating to outage, pricing, transmission congestion, and
combinations thereof. The systems and methods of the present
invention provide micro-level responsiveness since each grid
element's participation includes forecasting modeling associated
with "asset" availability at the macro level, as well as sub-EMS
level market economic modeling at the resource node at the micro
level, with all communications relating to the micro-level being
communicated through the coordinator to allow KWP, PSV, and
aggregation to form at least one PTB for grid element participation
and corresponding financial settlement for that participation.
[0133] Following the registration through the Coordinator, the
transformation relating to the active grid element enables the
active grid element to provide status and function for providing
normal and emergency grid operation, energy flows, transmission
losses, reactive power, operating reserves and/or grid
stabilization for the electric power grid, and the transformation
is registered in a database, and the database is registered with an
ISO, BA, Market Participant, NERC, utility service area, and/or
FERC. For security and management by the Coordinator, preferably
each of the at least one grid elements has a unique grid element
identifier associated with it. Where the Coordinator interacts with
or interfaces with legacy systems, in particular relating to
settlement, as illustrated in FIG. 1, the Coordinator preferably
updates the legacy systems associated with the grid and relevant to
the grid element(s) through the translator or other dedicated
software interface with the legacy systems.
[0134] The present invention also provides a multiplicity of
databases constructed and configured in network-based communication
for receiving registration data from a multiplicity of active grid
elements, wherein at least one Coordinator for routing messages
from the multiplicity of active grid elements through the network
connecting the databases, and wherein servers operating the
databases exchange information associated with the active grid
elements for affecting electric grid operations, reporting, and/or
stabilization, including service oriented architecture (SOA), Web
Services (Web Services Description Language "WSDL"), published
APIs, private APIs, and combinations thereof. Also, registration of
grid elements and information or data relating to their
transformation into active grid elements, including the attributes
of the active grid elements, are stored in the databases for
predetermined periods of time for use with economic and energy
accounting settlement associated with the active grid elements, and
the registration information associated with active grid elements
is used to determine attachment points to the electric power grid
for distribution and transmission of power, and may be further
combined with information about the generation, transmission, and
distribution system of the electric power grid, stored in the
database, and processed with analytics to simulate modeling for
attachment of active grid elements to the electric power grid.
Furthermore, the registration information associated with active
grid elements is used for communication with an EMS or other grid
subsystems necessary for normal or emergency grid operations.
Additionally, a registration is made for each active grid element,
and the registration complies with regulations and/or standards
established by Federal Energy Regulatory Commission (FERC) North
American Electric Reliability Commission (NERC), Independent System
Operator (ISO), Regional Transmission Organization (RTO), and/or a
governing authority for the electric power grid. In any case, the
server communicates a message to each of the at least one active
grid elements after the initial connection and registration through
the coordinator via the network, wherein the message is an IP-based
message, which is preferably transmitted over a plurality of
Ethernet capable communications networks, wired or wirelessly
transmitted over a communications network.
[0135] In preferred embodiments of the present invention, the
system further includes an interface that facilitates communication
of the message with the grid elements, the interface including an
IP-based interface, which is selected from the group consisting of
WiMax, High Speed Packet Access (HSPA), Evolution for Data Only
(EVDO), Long Term Evolution (LTE), any first or second generation
wireless transport method such as EDGE, or Code Division Multiple
Access, Ethernet, any proprietary Layer 1-4 protocol that contains
or is capable of transporting an Internet Protocol message, and
combinations thereof. The present invention may further include a
security interface associated with each of the grid elements
operable to receive security system messages from at least one
remotely-located security system, wherein the security interface is
standards-based or determined by the governing entity that
regulates grid operations for utilities, market participants or
grid operators.
[0136] In another embodiment of the present invention, an apparatus
for smart electric power grid communication is provided, including:
a grid element constructed and configured for electrical connection
and network-based communication with a server associated with an
electric power grid; wherein the grid element is transformed into
an active grid element after initial connection with the electric
power grid, and wherein the grid element includes a unique
identifier. Preferably, the transformation is automatic and/or
autonomous, following initial activation of the grid element, and
then the grid element is authenticated, registered, and then
performs the function intended to do within the grid. So then as
grid elements are transformed to active grid elements for
participation in the electric power grid, in particular for those
having a function intended as providing supply, including providing
the TDSP with a network simulation model, as part of the
registration process, the grid element has either loaded in its
processor and memory or is capable of downloading grid information
that allows for the grid to "self model" the impact of the
attachment of that element to the grid.
[0137] Preferably, the grid element transmits a signal or a message
to the server, more preferably through a Coordinator, for
registering with the electric power grid, and communicates
wirelessly with the server, preferably via IP messaging with the
server after attachment to the electric power grid. Such apparatus
embodiments for active grid elements include or are selected from
the group consisting of: a sensor, a power-consuming device, an
appliance, a meter, distribution and/or transmission elements,
telemetry elements, power supplying device, storage device,
controller, and combinations thereof.
[0138] In methods for electric power grid network management, the
present invention includes the steps of: providing at least one
grid element constructed and configured for electrical connection
and network-based communication with a server, energizing the at
least one grid element and/or connecting the at least one grid
element to an electric power grid; the at least one grid element
making an initial connection with the server via a network and
communicating a message to the server; and the at least one grid
element automatically transforming into at least one active grid
element for functioning actively within the electric power grid.
Preferably, the method further includes the step of: the at least
one grid element sending and/or receiving a message via
communication with the server via the network, wherein the message
is routed by a coordinator to the server. Also preferably, the
communication is wireless transmission, and includes wireless
IP-based messaging.
[0139] In operation of the system and methods of the present
invention, the communication further includes power event messages
that further include at least one of: status of device(s), supply
source(s), and/or demand; location of attachment; line losses;
distribution and transmission capacity information; and
combinations thereof, and the power event messages are based upon
inputs initiated from a market participant, a utility, or an
electric grid operator. Also, the power event messages include
information about PSV or PTB associated with the at least one grid
element.
[0140] While present invention relates generally to the field of
electrical power control systems and more particularly to systems,
methods, and apparatus embodiments for transforming grid elements
into active grid elements following an initial registration with
the electric power grid through a coordinator, following
transformation of the grid elements to active grid elements, the
electric power grid is functional for active management of power
supply from any electric power generation source or storage device
for introduction to an electric power grid, and/or load curtailment
for consideration as supply. Preferably, these systems and methods
and any apparatus embodiments of the present invention are in
compliance with standards that are currently contemplated and are
changing in response to the recognized need in the United States
and other countries where the electric utility grid is not fully
developed, but the demand for energy is expected to grow
substantially over the life of the invention (e.g., NERC, FERC
orders 745, 750, 755, etc.). Once transformed into active grid
elements, the present invention systems, methods, and apparatus
embodiments are operable to further provide for actively managing
power supply from any generation source supply or storage and/or
power supply from curtailment events applied to load consuming
devices, thereby creating operating reserves for utilities and
market participants, while optionally tracking power savings for
both the individual customer, broadly defined as any consumer of
electrical power whether this is an individual residential
consumer, a large commercial/industrial customer or any combination
thereof inclusive of retail electric providers and market
participants, as well as the electric utility or electric power
generation source supply (GSS), whether generating or distributing
power for the electric power grid. Therefore, active grid elements
include functionality for power generation supply, power storage
supply, and/or load curtailment as supply, as well as
load-consuming elements, telemetry elements, sensors, meters,
controls, and combinations thereof. Where active grid elements
change location or attachment to the electric power grid, then
their active grid element attributes change accordingly to indicate
the new, updated location and/or attachment point information or
data. Where a portion of the electric power grid changes due to
normal operation, or due to any element being out of service for
any reason, including dysfunction of distribution and/or
transmission of electric power along the lines to active grid
elements and/or the communications network changes or has
dysfunction, then preferably, the active grid elements are
acknowledged by the system through the coordinator upon their
reconnection with the grid and/or communications network.
Furthermore, any active grid element is replaced with a new or
substitute grid element, or taken out of service for more than a
predetermined period of time, then the replacement or substitute
grid element must be registered to be transformed into an active
grid element as with any new grid element being introduced into
service at any location or attachment point associated with the
electric power grid. Where reconfiguration, repair, or other
updating occurs, corresponding information related to the
reconfiguration, repair, or other updating associated with each
active grid element is communicated through the coordinator and
updated in the database.
[0141] Grid Functionality
[0142] The following descriptions and definitions are included
herein for the purpose of clarifying terms used in the claims and
specification of the present invention, in addition to explanation
of the relevant prior art, including the PRIOR ART figures and
those figures illustrating the present invention.
[0143] Power Distribution Engineering: Fundamentals and
Applications, James J. Burke, Marcel Dekker, Inc., NY (1994),
describes basic power electric power systems, including
distribution and transmission throughout an electric power grid,
and grid elements and basic functionality of grid elements, is
incorporated herein by reference in its entirety. Also, acronyms
and abbreviations and definitions for terms related to electric
power grids and systems and grid elements associated therewith, and
regulations and authorities related thereto, are known in the art,
and are also defined in the book Creating Competitive Power
Markets: the PJM Model, Jeremiah D. Lambert, Pennwell (2001), and
are incorporated herein by reference.
[0144] When curtailment or supply is provided in a distributed
manner from a plurality of sources through some of the grid
elements of the present invention, capacity is also created on the
transmission and distribution system that is used to carry the
physical energy to the load consuming devices, and/or the
attachment point of the supply devices, and those consumers at
their attachment point to the grid. This is sometimes referred to
in both the industry and the description of the present invention
as a "service point" and can represent any attachment point along
an electric grid whereby the physical layer of wires meets the
physical attachment of either load or supply that is used in
accordance with the present invention. The creation of capacity for
these "wired" networks is in itself new to the art, and is tracked
with the other messaging described in the present invention via the
Coordinator and with specific messaging that is used and identified
for the purpose of transmission and distribution capacity created
along every grid element that is used to distribute electric power
in the electric power grid. These created capacities are preferably
aggregated by service point, by attachment wires, by transformer,
by feeder wire, by substation/electrical bus, by transmission
line(s), by grid area, by geodetic points, by utility or MP service
area, by LMP, by balancing authority, by state, by interconnect, by
ISO, and combinations thereof. Thus, created capacity by active
grid elements according to the present invention, includes both the
actual capacity due to supply introduction or load curtailment,
and/or the location of the capacity created, which is a function of
the attachment point and with respect to the electrical bus
(substation) and/or transmission feeder that is supplying it. This
capacity is reported to the financial settlement system through the
Coordinator and/or translator; in the case of translator
communication, a translator interface is provided with the legacy
elements, e.g., OASIS; alternatively, the Coordinator and/or
translator tracks the capacity and has a market price input for
transmission costs for the purposes of providing a settlement for
the created capacity.
[0145] The present invention provides systems, apparatus, and
methods for managing a multiplicity of grid elements that function
within an electric power grid, and for managing the settlement
associated with their active participation in the grid. Following
registration and transformation into active grid elements, the
system provides for transmission and distribution of electric power
supplied by an electric utility and/or other market participants to
a multiplicity of the active grid elements (including but not
limited to devices and nodes), some of which consume power, some
supply power, some store power, and combinations. Active grid
elements may function within the grid to provide for supply and/or
load curtailment as supply. Each of the active grid elements have a
Power Supply Value (PSV) associated with its energy consumption
and/or reduction in consumption and/or supply (through generation
and/or storage). And each grid element further operates to
communicate (send and/or receive) messaging that is preferably
managed through a network by a Coordinator using IP-messaging for
communication with the active grid elements, with the energy
management system (EMS), and with the utilities, market
participants, and/or grid operators. However, in some cases,
messaging is provided between grid elements without passing through
a Coordinator.
[0146] Before describing in detail exemplary embodiments that are
in accordance with the present invention, note that the embodiments
reside primarily in combinations of system and apparatus
components, and processing steps, communications, protocols,
messaging and transport all related to actively managing power load
or supply on an individual subscriber basis and optionally tracking
power savings incurred by both individual subscribers and an
electric utility or other market participant, all of which directly
involve active grid elements of the present invention. Accordingly,
the systems, apparatus, and method steps components have been
represented where appropriate by conventional symbols in the
drawings, showing only those specific details that are pertinent to
understanding the embodiments of the present invention so as not to
obscure the disclosure with details that will be readily apparent
to those of ordinary skill in the art having the benefit of the
description herein.
[0147] As used in accordance with the description of the present
invention NERC is described and defined as follows:
http://www.nerc.com/files/Glossary.sub.--12Feb08.pdf. Balancing
Authority (BA), as used in accordance with the description of the
present invention is defined as the responsible entity that
integrates resource plans ahead of time, maintains
load-interchange-generation balance within a Balancing Authority
Area, and supports Interconnection frequency in real time.
Balancing Authority Area (BAA), as used in accordance with the
description of the present invention is defined as the collection
of generation, transmission, and loads within the metered
boundaries of the Balancing Authority. The Balancing Authority (BA)
maintains load-resource balance within this area (BAA).
[0148] Also, if demand changes so abruptly and quantifiably as to
cause a substantial fluctuation in line frequency within the
utility's electric grid, the utility must respond to and correct
for the change in line frequency. To do so, utilities typically
employ an Automatic Generation Control (AGC) process or subsystem
to control the utility's regulating reserve. This subsystem when
coupled with transmission, generation and distribution telemetry,
processors, and industry standard software in its aggregate is
referred to as an Energy Management System (EMS) as exemplified and
manufactured for the energy sector by many OEMs such as, by way of
example, GE, OSlsoft, and Areva. To determine whether a substantial
change in demand has occurred, each utility monitors its Area
Control Error (ACE). A utility's ACE is equal to the difference in
the scheduled and actual power flows in the utility grid's tie
lines plus the difference in the actual and scheduled frequency of
the supplied power multiplied by a constant determined from the
utility's frequency bias setting.
[0149] The aggregation of the longstanding, unmet needs in the
relevant art is the basis for new innovation, including solutions
offered by the present invention, having systems and apparatus
components that include the following attributes: [0150] a. The
system, apparatus, methods and devices utilize standards-based Open
Systems Interconnect (OSI) Layer 1-4 communications protocols with
a plurality of security encryption methods. [0151] b. The
communication layer is Internet Protocol (V4 or V6 or its
derivatives thereof) based such that the messages, instructions,
commands, measurements and telemetry is transmitted via physical
layer delivered Ethernet, first generation wireless communications
methods (analog or digital), second generation communications
methods such as Code Division Multiple Access (1XRTT), Enhanced
Data Rates for GSM Evolution (EDGE), third generation protocols
such as Evolution for Data Only (EVDO), High Speed Packet Access
(HSPA), Fourth Generation protocols Long Term Evolution (LTE), IEEE
802.11 (X) "WiFi", or any derivative standard approved by the IEEE,
International Telecommunications Union or any domestic or
international standards body or any proprietary protocols that can
operate in near real time and contain an Internet Protocol packet
for the transmittal of their command, control, telemetry,
measurement, verification, and/or settlement information, whether
wired or wireless. [0152] c. The command and control for the
purpose of (b) can be created and controlled from a centralized
processor, a distributed processing apparatus, or at the device
level. [0153] d. The aggregation of these methods result in the
creation of real-time load curtailment that may be classified
broadly as "Demand Response", macro or distributed generation and
can be native load (i.e., real-time supply) as required by the
electric power grid where the invention is utilized, and also be
utilized to create Operating Reserves as defined by NERC, FERC,
and/or any other governing body that regulates the operation of an
electric power grid and/or utilities or other market participant
providing power to an electric power grid.
[0154] FIG. 3 is a schematic diagram illustrating at least one
coordinator and a multiplicity of grid elements within a system and
methods of the present invention. Grid elements illustrated for
example, and not limitation of the present invention, include smart
appliances, smart meters, building control systems, sensors,
storage devices, power generators (including alternative energy
sources like wind, solar, water, etc.), active load clients (ALCs),
active load directors (ALDs), active supply clients (ASCs), active
supply directors (ASDs), controllers, coordinators, distribution
elements, transmission elements necessary for grid operations and
stability, and combinations thereof. Following registration with
the system, and transformation to active grid elements for managed
participation within the electrical power grid and corresponding
systems and methods of the present invention, the active grid
elements communicate with and through at least one coordinator and
to the energy management system (EMS) or other grid operations
subsystems, such as RTO/ISO operations systems, transmission
operation systems, distribution operation systems, and function
according to their intended purpose. By way of example and not
limitation, a smart meter provides meter functions to track and
communicate load consumed by one or more active grid elements
and/or devices; a thermostat or building control system provides
for HVAC and/or environmental conditions indication and control,
including temperature management, humidity, lighting, security,
etc.
[0155] FIG. 4 is a schematic diagram illustrating grid elements,
attachment points, and telemetry through a network associated with
the systems of the present invention. FIG. 4 illustrates at least
one controlling or participating entity, selected from the group
consisting of a grid operator, utility, market participant, retail
electric provider and/or distributor, and combinations thereof, an
EMS, in electrical power connection and communication with a
multiplicity of active grid elements, all within at least one
balancing authority (BA), and all connected through an electrical
power grid and communications network(s). The active grid elements
provide telemetry and messaging relating to a multiplicity of grid
element attributes and/or grid element factors, including but not
limited to attachment point information, geodetic information,
status, capacity, grid element identifier(s), grid element
profile(s), power consumption and flows (instantaneous and
historical), and combinations thereof. Preferably communication
among active grid elements and the controlling or participating
authority is provided over a network and routed through at least
one coordinator via Ethernet and/or IP connectivity. A counter may
also be included for tracking packets, and packet switching and
routing is provided within the systems and methods of the present
invention, wherein network communication for energy routing and
energy information routing is provided with a messaging structure
having layering, similar to an Open Systems Interconnection (OSI)
model including layers for application, presentation, session,
transport, network, data link, and physical communication
functions, which defines the communications tasks of the system,
and which provides a vertical set of layers forming a communication
infrastructure for interconnection over public and private
networks. Information describing general OSI model communication
structures and functionality is known to one of ordinary skill in
the art and described in Data and Computer Communications by
William Stallings, MacMillan NY (1985), which is incorporated
herein by reference in its entirety.
[0156] The structure of OSI modeling for the systems and methods of
the present invention are considered to provide communications
networks for use in coordination with the physical structure and
network of the electric power grid and the active grid elements
registered therewith, and may further include TCP/IP. Ideally, the
OSI model for communication network would be integrated with the
physical network for electric power distribution and transmission,
including active grid elements and controls, database, server,
coordination with supply and load, etc. The present invention
provides for the application of an energy network (i.e., the
electric power grid) and a communications network, including the
OSI-based model, and coordination to integrate the messaging with
the power movement through the system.
[0157] FIG. 5 is a schematic diagram illustrating an exemplary
network node configuration for grid elements registration and
communication. In one embodiment of the present invention, the
network for communication involving active grid elements and the
coordinator and/or other grid elements includes a packet-switched
network that is used to accept packets from a source node and
deliver them to a destination node, such as in the case wherein a
grid element makes initial registration with the system by sending
an initial communication to a coordinator, and the coordinator
responds and the systems and methods of the present invention then
provide for automatic and/or autonomous transformation into active
grid elements, wherein at the moment of registration the active
grid elements are functional within the electric power grid to
perform their designated or predetermined operations and roles or
functions. FIG. 3 illustrates an example network configuration
illustrating a multiplicity of paths or routes through a network
for communication and energy routing within the electric power
grid. The connections between active grid elements and
coordinator(s) and other active grid elements are illustrated. In
preferred embodiments of the present invention, at least one
balancing authority (BA) includes at least one coordinator in
network-based communication with a multiplicity of active grid
elements, and further connected in electrical and data
communication connections with at least one source of power and at
least one EMS. By way of example, a new grid element prior to
registration with the system of the present invention initiates a
signal or message via the network following its initial energizing
with power from any source (battery or externally-supplied power),
wherein initial message includes at least one of the following:
unique grid element identifier, equipment identifier, class of
service information, capability, capacity, function information,
geodetic information (GPS, physical address, etc.), attachment
point, IP address information, communication format and content
information, security, authentication information, and combinations
thereof. Thus, after initial energizing of the at least one grid
element, the grid element searches for at least one network
available for communication with the electric power grid,
preferably with the coordinator, and determines how to engage with
the coordinator or at least to establish initial network
communication with the coordinator, identification of network
protocol, etc. A network identifier is included in the
transformation and network interface for each of the at least one
grid elements. Preferably, messaging between the at least one grid
element and the at least one coordinator is provided by IP-based
messaging over the network. Following the initial response and
registration of the at least one grid element, there is a
transformation into at least one active grid element, which
provides that each of the at least one active grid elements is
operable to function automatically and/or autonomously for its
predetermined function within the electric power grid, including
telemetry at predetermined intervals, continuously, or when change
in state occurs for each of the at least one active grid
elements.
[0158] In preferred embodiments of the present invention, the
registration of grid elements may be provided using one or more of
the following for providing unique identification for each grid
element: messaging and/or signaling between active, inactive, IP
address, V4, V6, proprietary, mesh or direct, TDM or pots, analog
or digital telemetry, RFIDs, and combinations thereof. A
registration for grid elements may further include registration
into a home network or a visitor network, and/or movement of any of
the active grid elements (following transformation after initial
registration) to different locations or geographies and/or to
different or new attachment points provides for at least one update
of status for the movement or change for that active grid element.
Attachment points are preferably provided in a location register
that is defined by proximity to an electric bus or substation
within the electric power grid, or any other predetermined geodetic
location within the physical structure of the electric power
grid.
[0159] FIG. 6 is a schematic diagram illustrating a distribution
automation communications network as part of systems and methods of
the present invention, including a main communications ring having
a multiplicity of active grid elements associated therewith, and
further including at least one master control center and
corresponding database, SCADA master, AMR master, switches and
electrical network lines and connections (copper wire) and
communications network lines and connections (fiber) and at least
one distributed ring having a multiplicity of active grid elements
associated therewith. In this exemplary network sector, the active
grid elements and electrical power network and communications
network are included within one balancing authority (BA). Several
active grid elements function as meters and/or smart meters and
provide for automated meter telemetry through the network from the
grid elements to at least one coordinator. In a typical network
architecture, at least one core network for a balancing authority
is provided, and wherein a multiplicity of grid elements are
constructed and configured in electric power transmission and/or
distribution connection and network-based communication connection
for sending and receiving messages between each of the grid
elements and at least one Coordinator.
[0160] FIG. 7 is a schematic diagram showing energy systems
operations and communications network-based connections as part of
systems and methods of the present invention, including
compatibility and/or compliance with US National Institute for
Standards and Technology (NIST) standards applicable to
transmission and/or distribution lines for the electric power grid
in communications network connectivity with a multiplicity of grid
elements, market participant(s), utility or electric power
generator supplier and/or third party energy provider (for GSS, as
described hereinbelow), an energy market clearinghouse (ECM), an
aggregator for providing at least one power trading block (PTB) for
settlement for energy supply and/or curtailment as supply providing
by at least one of a multiplicity of grid elements, including power
consuming devices, ALCs, ALDs, ASCs, ASDs, and at least one
coordinator.
[0161] FIG. 8 is a schematic diagram showing a basic AGC/energy
management system (EMS) representation.
[0162] The present invention provides automated advanced
settlements for IP-based active power management (load and supply)
systems having active grid elements, which have predetermined
functionality within the electric power grid, and are addressable
with IP-based messaging within the communications network by an
active load director (ALD) and/or Coordinator wherein the messaging
occurs over communication networks, such as the Internet. The
present invention improves and expands upon prior art systems and
methods, including U.S. Pat. No. 5,560,022 issued Sep. 24, 1996,
filed Jul. 19, 1994 by inventors Dunstand, et al., and assigned on
the face of the document to Intel Corporation, for Power management
coordinator system and interface, which is, including its
specification and figures, incorporated herein by reference in its
entirety.
[0163] US patent applications for the following: U.S. patent
application Ser. No. 13/528,596 filed Jun. 20, 2012, entitled
METHOD AND APPARATUS FOR ACTIVELY MANAGING ELECTRIC POWER OVER AN
ELECTRIC POWER GRID; U.S. patent application Ser. No. 13/549,429
filed Jul. 14, 2012, entitled Method and Apparatus for Actively
Managing Electric Power Supply for an Electric Power Grid; and U.S.
patent application Ser. No. 13/563,535 filed Jul. 31, 2012,
entitled SYSTEM, METHOD, AND APPARATUS FOR ELECTRIC POWER GRID AND
NETWORK MANAGEMENT OF GRID ELEMENTS; all by common inventor to this
patent application, Joseph W. Forbes, Jr., each of which, including
their complete specification, figures and descriptions, are
incorporated herein by reference in their entirety, provide
detailed descriptions of the systems, methods, and apparatus
embodiments relating to active management of electric power grids
and their corresponding supply and demand components. By way of
example, Active Supply Director (ASD) and Active Supply Client or
Element (ASC) provide for the corresponding management of electric
power available or actually supplied to the electric power grid,
whether by Generation Source Supply (GSS) elements or by Storage
Source Supply (SSS), including battery or fuel cell, or compressed
air, stored water, or any subsystem that includes a potential for
discharging electricity as stored energy to the electric power
grid, available for discharge or actually discharged into the grid.
In any case, whether electric power supply for the grid is provided
by generation or load curtailment, the supply is evaluated and
rated by Power Supply Value (PSV) and Power Trade Block (PTB),
which indicates the amount of power, including aggregated amounts
acceptable for settlement by the grid, which are communicated by
the active grid elements through the Coordinator and then to an
energy management clearinghouse for settlement based upon PSV, PTB,
and market factors associated with and communicated by the active
grid elements and timing, duration, quality, type of event (for
supply and/or demand response) within the electric power system
energy management to the coordinator. Preferably, all information
required for settlement is communicated within the systems and
methods and by apparatus embodiments of the present invention,
automatically and/or autonomously and preferably with IP-based
messaging via the network; this information is routed by at least
one coordinator and stored in memory in a database that is
accessible by the energy management clearinghouse.
[0164] Each active grid element associated with supplying power
and/or providing load curtailment within the electric power grid,
includes with its attributes at least one Power Supply Value (PSV)
associated with its activity and function within the grid. Power
Supply Value (PSV) is estimated, modeled, measured, and/or
determined or calculated at the meter or submeter, building control
system, supply source, or at any device or controller that measures
electric power within the standard as supplied by the regulatory
body(ies) that govern the regulation of the grid. PSV depends on
operating tolerances, operating standard for accuracy of the
measurement. Notably, the PSV provides a uniform, systematic unit
for addressing the power curtailment or power supply that is
responsive to an energy management system (EMS) or equivalent for
providing grid stability, reliability, frequency as determined by
governing authority, grid operator, market participant, utility,
and/or regulations applicable to the electric power grid
operations. The PSV enables transformation of curtailment or
reduction in power, in addition to the introduction of power supply
to the grid, at the device level by any system, apparatus, and/or
device that sends or receives an IP message to be related to or
equated to supply as presented to the governing entity that accepts
these values and award supply equivalence. PSV may be provided in
units of electrical power units, flow, monetary equivalent, and
combinations thereof. The PSV and/or PTB addresses the longstanding
unmet need within the electric power management systems for a
consistent or standard unit(s) that provide for blocks or bundles
of energy are introduced, aggregated, and settled; the prior art
nowhere teaches or discloses these functional units. Thus, the
present invention includes a PSV that provides a unit for measuring
and settling for each active grid element the power available
for/introduced to the electric power grid and/or the curtailment
power available (consistent with FERC orders 745, 750, 755) as a
requirement for providing supply to the power grid, and,
particularly wherein the supply to the power grid is provided for
grid stability, voltage stability, reliability, and combinations
thereof. Notably, "high performance reserves" from FERC order 755
covers for "deadband", i.e., the time between receipt of
reg-up/reg-down, recognition of that order, and response to impact
on the grid, which is about 5 minutes for high performance
reserves, which are faster for supply than the traditional
utilities.
[0165] PSV is preferably settled as traditional power delivery or
curtailment systems at the nearest interconnection point, Location
Marginal Price (LMP), node, transmission interconnection, balancing
authority, utility service area, retail electric provider service
area, ISO, state, and combinations thereof, i.e., settlement is
available at the point of delivery and/or acceptance (or attachment
point), and is facilitated by ALC, ASC, Coordinator, metering
device, smart meter, sub-meter, and combinations thereof, or any
revenue grade device accepted by the governing authority to
determine PSV and/or settlement for each active grid element. Also
preferably, PSV includes consideration for line losses proximal to
those devices and/or grid elements, if not through real-time
metrics then through modeling and/or estimation. Furthermore,
regarding PSV and other metrics, where no real-time metrics for
verification and settlement exist, modeling is used. Preferably,
analytics is used in connection with the present invention for
modeling, estimation, optimization, and combinations, such as those
analytics taught by U.S. Pat. Nos. 8,180,622, 8,170,856, 8,165,723,
8,155,943, 8,155,908, 8,131,401, 8,126,685, 8,036,872, 7,826,990,
7,844,439, 7,840,395, 7,729,808, 7,840,396, 7,844,440, 7,693,608,
and US Patent Application Publication Nos. 20070239373,
20080262820, 20080263469, 20090076749, 20090083019, 20090105998,
20090113049, 20100023309, 20100049494, 20100168931, 20100268396,
20110082596, 20110082597, all of which are incorporated herein by
reference in their entirety.
[0166] The present invention methods, systems, devices, and
apparatus provide transformation of grid elements to active grid
elements following their automatic registration with IP-based
messaging communicated via the network and preferably through a
coordinator. Following registration, the active grid elements
operate according to their respective intended functions, and also
preferably continue to have automatic communications and messaging
via the network through at least one coordinator. Because of the
automatic and preferably autonomous registration and ongoing
messaging, active grid elements operate collectively for managing
flow of power for an electric grid, micro grid, or other system, or
combinations thereof, more particularly the supply of electric
power for the grid, whether by generation, storage for discharge,
electric vehicles (EV), which function as transportable storage and
load consuming devices, either standalone or in aggregate, (and
must be tracked to ensure proper settlement and grid stability
management), and/or load curtailment, and function to ensure grid
stability and to supply electric power from any source of power
generation, storage, and/or curtailment that equates to supply.
[0167] According to the present invention, grid stabilizing metrics
including voltage, current, frequency, power factor, reactive and
inductive power, capacitance, phase control, and/or any other grid
metric that is required by a grid operator, market participant,
utility, and the like, to operate and maintain electric power grid
stability as determined by the grid operator or the governing
entity therefor. Preferably, these metrics are monitored and/or
measured at a multiplicity of points, and more preferably using
active grid elements and their attributes and status information
throughout the electric power grid, including but not limited to
locations within or at the distribution system, transmission
system, electrical bus (substation), generation source, supply
control devices, load control devices, load consuming devices
(particularly those involved in curtailment activities), at least
one Coordinator, and combinations thereof. The metrics apply to any
size and type of active grid element, regardless whether the
generation source is macro in nature, e.g., large scale generation
such as large coal, nuclear, gas or other traditional or
non-traditional sources of generation, micro-grid generation,
emergency back-up power generation, alternative energy generation,
e.g., wind, solar, etc., or a power storage device or fuel cell
that is potentially available for discharge.
[0168] Also, at least one of the active grid elements may include
client devices or the associated power consuming or generation
control devices have the ability to independently execute commands
from an Active Load Director (ALD), Active Load Client (ALC), a
3.sup.rd party Energy Management System (EMS), Active Supply
Director (ASD), Coordinator, Generation Source Supply (GSS),
Storage Source Supply (SSS), transmission/distribution capacity,
messaging, settlements, security, and combinations thereof, that
provide for both load consuming and generation to engage with the
electric power grid at attachment points with assured grid
stability as indicated by the grid stability metrics for compliance
with requirements of the grid operator, utility, market
participant, grid governing authority, and/or any other regulations
applicable to the electric power grid. All of these active grid
elements preferably receive their commands and send communications
and/or messaging via an IP message via a Coordinator or Layer 3
router capable of handling all current and future iterations of IP
messaging contemplated during the life of this invention.
[0169] Also preferably, all messaging to and from active grid
elements is controlled, managed, and transmitted through the
Coordinator, which communicates between the many active grid
elements, including and following their initial registration, and
the EMS and/or grid operator, utility, governing authority, and
combinations thereof. More preferably, all commands and
communications are routed through and by the Coordinator, which is
constructed and configured for direct and/or wireless communication
with the multiplicity of grid elements, and further includes
components of processor, memory, persistence layer, memory cache,
messaging engine, security interface, status and/or
change-in-status indicator, geodetic locator, telemetry,
connections with the network, software operable for managing and
changing the connections, database with software operable for
storing and analyzing data associated with transmission and
distribution attachments, service points, active grid elements,
registration, authentication, PSV, PTB, identification, capacity
and capability of load and supply, software version control for
active grid elements, software improvement control, software for
settlement, and combinations thereof. Other switch elements, which
may be included as active grid elements, that may be applicable to
the Coordinator, and are included with the present invention
include customer identification and authentication, customer
security, attachment information and capacities, reservations for
utilizing the transmission and distribution system, signaling to
the electric grid or its operator the plurality of all the above.
The Coordinator functions as an "energy router" whereby the
messaging required to route supply, demand and
transmission/distribution capacity to and from the grid is
differentiated from pure communications routing and relates to grid
stability and improved grid performance. Thus, the Coordinator is
not merely functional as a traditional telecommunications router,
but further includes the aforementioned messaging, management, and
control functionality required for supply or curtailment to the
electric power grid. The Coordinator is consistent with compliance
as contemplated in the aforementioned FERC orders where frequency
deviations, security, and grid performance are all now needed in an
era of aging grid infrastructure and a changing and dynamic load
environment where the legacy macro grid and the interim "Smart
Grid" elements are not capable of responding to the new needs that
FERC and NERC have identified and charged the market participants
to solve, which have not yet been solved by any prior art, but
which are addressed by the present invention. The energy routing
function of the coordinator serves as a traffic manager, and a
messaging engine, to track all the active grid elements, secure
reservations and settlement information on the electric power grid
and the interface for one-to-many (i.e., one port for EMS to the
many active grid elements under the control of an EMS and supplying
grid stability from the many to the one) allowing for microelements
and distributed generation and distributed load curtailment to
perform with the macro grid without taxing and destroying the
legacy infrastructure beyond its capabilities and limitations; the
Coordinator is further operable for tracking and maintaining status
of all devices within its defined boundaries, or as described
hereinabove with respect to PSV, or determined by the governing
authority for the grid, which includes a balancing area, an ISO, a
utility, a market participant, and combinations thereof.
[0170] Preferably, the Coordinator manages all registered active
grid elements according to their characteristics, profiles
associated therewith, location, and capability for responsiveness
to the various electric power grid resource requirements. The
Coordinator further operates to match and prioritize these
registered active grid elements and provides messaging of their
information and/or matching and prioritization to communication
elements, including wireless and/or wireline carriers, so that the
messaging is then prioritized through any or all of the networks
for communication of any messages to the utility, market
participant, grid operator, EMS, and combinations thereof, based
upon the grid resource requirements at any given time. Thus, the
Coordinator provides priority "flags" on messaging that may be
communicated over existing telecommunications infrastructure to
provide grid stability and resources messaging with priority
messaging over other information transmitted through those
communications networks regardless if they have been configured to
offer priority or "class" of service or not, VPNs or not. In
particular, since electric power generation, distribution and
transmission is part of critical infrastructure and provides an
asset for national security in many countries, including the United
States of America, the present invention provides for enhanced
critical infrastructure security with the priority messaging
associated with the Coordinator and allows the Coordinator to take
advantage of new chip and ASIC technologies that will accommodate
multiple routes, VPNs, APNs, and IP addresses per active grid
element, ALC, ASD, GSS, SSS, Smart Meter, Service Point,
transmission, distribution element or combinations thereof.
[0171] The Coordinator is operable for and includes Layer 1-4 for
communication, but additionally, and significantly, the Coordinator
further tracks and communicates and controls where elements are
attached to the grid, makes or communicates decisions about how the
resources are used either with or without communication to any
active grid element, including but not limited to ALD or ASD, or
EMS, communicates the status of any and all active grid elements to
legacy distribution automation and transmission reporting
subsystems and provides for new methods for direct contribution by
active grid elements to the grid stability through load curtailment
and/or supply from any source, and for settlement of same, and the
security, authentication, initial registration of the devices with
the grid, ALD, ASD, market participant, grid operators, their
legacy subsystems and/or EMS for the electric power grid; and
change of status for those active grid elements; and combinations
of these, while simultaneously facilitating and routing those
messages to the appropriate subsystem to achieve the supply,
curtailment, and/or grid stability requested by the legacy
subsystems, or through the present invention, all with IP-based
messaging. Most preferably, using digitally encrypted secure IP
messaging delivered through a network via Ethernet, wireless
messaging, or proprietary methods, including carrier-grade wireless
and/or wired networks for communication.
[0172] SCED--Security Constrained Economic Dispatch
[0173] Security messaging is provided by systems and methods of the
present invention. NIST and NERC provide standards for encryption
of data, market data is provided by rules according to those
standards. Data generated in the systems and methods of the present
invention for automated financial settlements associated with the
grid element participation, due to the increased accuracy and
timeliness of the data, are preferably provided with secure
messaging and access consistent with the standards for NIST and
NERC, which are incorporated herein by reference in their entirety
(including the version published as of the date of the filing of
the present invention). Preferably, this data is secured and access
is provided to market participants on a subscription basis,
provided that they agree to all security and data usage
requirements associated with market rules and privacy rules and/or
laws governing the electrical grid and/or energy markets. If
regulatory bodies or market governing bodies deem the data to
significantly advantage those who have adopted it, due to the speed
and execution of trading energy consumption, forecasting and
projection, then the market may purchase subscription access. By
way of example, security is provided in at least one form, such as
VERISIGN and PAYPAL certificates provided to ensure secure
financial transactions; group keys, dynamic keys, certificates,
VPNs, etc. used with the communications of financial settlement
messaging according to the systems and methods of the present
invention. Verisign authentication, and functionally similar
security services associated with electronic communications of
financial settlement, which are incorporated herein by reference
herein, includes SSL (secure socket layer), PKI (public key
infrastructure), Verisign Trust Seal, and Verisign Identity
Protection (VIP) services are owned by Symantec.
[0174] Priority messaging for financial settlement is also provided
by systems and methods of the present invention. OSI equivalent for
financial messaging, including price, consumption, location,
trouble, loss of connectivity, increase or decrease consumption or
supply (associated with price), etc. Prioritization for
participation messaging is provided under the present invention;
initial registration is followed by messaging associated with the
grid element relating to participation, profiles, etc.
Authentication is preferably included with registration, and any
and all updating or changes to settings, profile, preferences, and
particularly including location. Location defines resource node,
attachment point, losses, electrical bus, PSV, PTB, and
combinations thereof, and therefore, financial settlement factors
and final value of settlement for the participation for each of the
grid elements.
[0175] The Coordinator operates further for communication of all
telemetry, settlement, tracking, and combinations thereof for each
active grid element. All active grid elements associated with the
grid for supply and/or load curtailment are registered with the
Coordinator and are routed within one or more ports within the EMS,
for example as illustrated in the Figures; thus, the Coordinator
and its application or functionality within the electric power grid
sends signals, telemetry and messaging for primary frequency
control, grid stability, control events, dispatch schedules for
supply sources (both pre-scheduled and dynamic/real time in
response to electric power grid conditions), and combinations
thereof through messaging and coordination with the active grid
elements. The Coordinator also preferably includes functionality
for clearing and reporting to and with transmission reservations
subsystems associated with the active grid elements. By way of
example, prior art transmission reservations subsystems can be
represented by companies such as OATI's OASIS transmission
reservation system (illustrated at the Internet website
www.oatioasis.com), which is overseen and regulated by FERC, but
whose clearing and reporting is deficient in enabling reservations
below macro transmission levels, and whose reservation systems
include "firm" capacity and "non-firm" capacity that has very
little value since its reliability is not assured. The present
invention solves many of these problems and creates "actual
measurable and verifiable transport capacity" by enhancing power
distribution, settlement, and combinations thereof, by grid
element, by service point, by device and by consumer. Additionally,
telemetry for settlement for curtailment, supply from storage, and
combinations thereof, are managed through the Coordinator. The
Coordinator is further constructed, configured, and operable in
IP-based or proprietary messaging communication, for providing a
routing and control architecture and methods analogous to the OSI
model used in telecommunications networks worldwide, applied for
all active grid elements management and for supply, whether GSS or
SSS, and load curtailment management for any of the multiplicity of
active grid elements, and grid stability. The messages contemplated
by this type of energy routing and capacity creation in itself
creates the potential for a new standard for achieving FERC and
NERC goals while seamlessly integrating into legacy subsystems of
current art of macro electric utility architecture.
[0176] The method, system and apparatus embodiments of the present
invention further provide that the active grid elements are
operable to send change in state messages in lieu of a constant
stream of IP messages via a telemetry path. The change-in-state
messages provide the ability to only communicate the "deltas" (or
change in state) and have the ALD, ASD, and/or server transmit,
send, or stream the telemetry from the last "known value" until
that last known value has changed, by communicating a "delta"
message, rather than constantly streaming values, and may use
"machine to machine" communications, text telemetry, or any low bit
rate telemetry method that meets the requirements as established by
the governing entity, but is capable of complying while
simultaneously utilizing the transmission bandwidth and latency
that is available at a service point or active grid element
location. These change-in-state messages associated with the active
grid elements preferably include the necessary information to
report the Power Supply Value (PSV), PTB, and/or any other grid
stability messages on an event basis rather than merely a telemetry
basis and to send those messages through a server, and are
transmitted to an energy management system (EMS) via a format as
determined by the grid operator, microgrid operator, and/or other
grid control entity while simultaneously achieving primary
frequency control and grid stability at the service point and/or
active grid elements and storing at the ALC, ASD, ALD, ASD or
combinations thereof the necessary information in granular format
sufficient to transmit for settlement or measurement and
verification processes later either when better transmission speeds
are available or retrievable by a manual intervention such as a
smart phone, tablet or drive by apparatus where the memory may be
downloaded to a mobile client.
[0177] The systems, methods, and apparatus embodiments of the
present invention further provide for commands issued either
directly by the EMS, Coordinator, ASD, ASC, ALD, ALC, load
consuming device, "Smart Electric Meter" and its subcomponents
(processor/memory), or by programming any active grid element, for
example, a client device such as a programmable thermostat or
building control system, wherein the commands anticipate the
activation of a load curtailment event for any load consuming
device (such as an HVAC system, a system profile that has been
programmed for supply side indices such as market price of power or
Operating Reserves or load side indices that take a consumer's
preferences into account, or any other sensor) or the activation of
a supply or demand event for any supply source associated with the
electric power grid.
[0178] The balancing areas (BAs) provide for opportunities for the
electric power grid and/or a multiplicity of grids that are
constructed and configured for networked communication and power
distribution therebetween. In one embodiment of the present
invention, communication with active grid elements passes through
or is routed by at least one Coordinator for providing the
one-to-many coordination of communication, messaging, etc. between
the many active grid elements and the EMS, inside a given BA or
between BAs, which may involve at least one Coordinator for each
BA, thereby providing for managed, coordinated cross-communication
of status, change-in-status, grid stability metrics, control
messages, and combinations thereof.
[0179] The present invention systems and methods provide
hereinbelow for power trade blocks or power trading blocks (PTBs)
for facilitating the collaboration across balancing areas and
regions for supply and load curtailment management, for increasing
power available, operating reserves, and/or grid stability. In
preferred embodiments of the present invention, at least one PTB is
introduced and/or provided to the electric power grid, including
method steps of: valuing, trading, selling, bartering, sharing,
exchanging, crediting, and combinations thereof. Thus the present
invention provides for electric trading markets across BAs or
microgrids or individual active grid elements, including load
consuming customers or supply sources, whether generation, storage,
distribution or transmission.
[0180] Telemetry, measurement, verification, PSV, PTB, and other
factors described herein, in compliance with FERC 745, 750, and
755, provide with the present invention the capacity for active
grid elements functioning for providing curtailment as operating
reserves to be compensated for megawatts at the clearing price, and
for supply to be provided or indicated as available to be provided,
and compensated or settled for megawatts at the clearing price.
Clearing prices are either determined by many attributes including
their location of where the power is delivered or accepted by a
generator of power or a purchaser of power. The term "Locational
Marginal Pricing (LMP)" refers to a node where power is either
delivered from a generator or accepted by a purchaser. A node
corresponds to a physical bus or collection of buses within the
network or any other geodetically defined boundary as specified by
the governing entity. A load or supply zone is defined as an
aggregation of nodes. The zonal price is the load-weighted average
of the prices of all nodes in the zone. A hub is defined as the
representative selection of nodes to facilitate long-term
commercial energy trading. The hub price is a simple average of
LMPs at all hub locations. An external or proxy node is defined as
the location that serves as a proxy for trading between
ISO-Balancing area and its neighbors. According to the present
invention, the at least one grid element(s) includes transmission
or distribution control node, monitoring node, telemetry node,
routing node, electrical routing node, fault protection node,
generation node, load control node, devices (active and passive),
sensors, etc., wherein any node includes an interface and/or an
attachment.
[0181] For vertically integrated utilities that do not have open
markets as ISOs, their delivery or acceptance of power can occur at
the boundaries of their "Balancing Area", which is defined as the
geography where their transmission and distribution system extends
and is subject to grid stability maintained by that utility.
Balancing Authority boundaries can also be delivery points or (LMP)
pricing points. It should be noted that vertically integrated
utilities are subject to the same FERC and NERC rules as decoupled
utilities in ISOs, except in vertically integrated utilities, local
public utility commissions have more authority to enforce and
enhance rules since the rate base is being charged for improvements
to the grid within the balancing area (BA) that the utility serves.
FIG. 17B is a table illustrating three FERC orders (745, 750,
755--all issued in 2011) and their applicability to the electric
power grid load management and distributed supply addressed by the
various systems, including active grid elements and their
registration and functionality within the system according to
methods and apparatus embodiments for present invention. The trend
in the world market is to inject market forces to utilities such
that they must follow new FERC rules that permit the use of demand
response technologies/load curtailment technologies to promote the
need for fewer large scale, primarily fossil fuel power plants.
[0182] Power is generally traded in terms of "Capacity"--the
reserved peak amount of power that a generator agrees to reserve
for the utility, market participant, or REP--and "Energy," defined
as the amount of power consumed by the utility, market participant,
REP or any entity that is authorized to buy, sell or distribute
power for the electric power grid; consumers, particularly
commercial accounts, also purchase power in this manner. Energy is
settled on the wholesale market in "MegaWatt Hours", which is
defined as one (1) million watts of electricity consumed at a
metering point, or interchange of power such a LMP, transmission
tie point between two utilities, a commercial customer large enough
to consume such an amount, a utility (generating or distributing)
or a market participant including a REP that generally purchases
the power from a generating utility and utilizes the distribution
network to supply its power purchased at the wholesale level and
distributes its power to end consumers/customers generally in
smaller increments of measurement "kilowatt hours (kWH)." These
increments are important due to the introduction of programs
involving utilizing curtailment technologies enabled by FERC Order
745, 750, 755 whereby utilities, market participants, REPs and CSPs
may aggregate their curtailment/DR and/or supply in increments of
"kW-representing a capacity figure" and "kWH" which represents
avoided energy. Peak "capacity" charges are settled based upon
intervals whereby the instantaneous peak (kW/MW) determines the
"capacity" charge.
[0183] In particular, by way of more detailed explanation, FERC
issued a series of orders (745, 750, 750-A, 755) that have had a
pronounced impact on the injection of new technologies,
particularly distributed load resource, curtailment, demand
response technologies, and distributed supply sources, to the
market to be implemented across all of the US and with direct
applicability to World markets. FERC Order 745 provides that
utilities, market participants, CSPs, REPs or any other entity that
can aggregate a minimum trading block of power that can be accepted
into the market, BA, utility service area, or regional trading area
(RTO) must be compensated for such curtailment/load resource and
demand response technology at the clearing price at the nearest LMP
as though it was generation; this provides that active grid
elements associated with these supply and/or curtailment activities
may be individually tracked, managed, reported, and compensated
based upon their individual contribution to the aggregated
settlement. Said plainly, "Negawatts" have the same value as
"Megawatts." Controversial, particularly to those utilities that
still have the antiquated practice of rate base recovery of assets
to insure profits, the conditions of which these "Negawatts" are
compensated as "Megawatts" place a high value on those
curtailment/load resource/demand response technologies that can
create utility Operating Reserves for the benefit of grid
stability. Operating Reserves, previously defined, come in
different capacity and energy products or their equivalencies in
the case of curtailment/load resources/demand response and are
compensated at the nearest LMP based upon their ability to perform
to the same level of measurement, verification, responsiveness
(latency) and settlement as generation. This high standard has the
practical effect of rewarding those advanced technologies that can
perform as generation equivalencies (load resources), while still
allowing capacity products (traditional and advanced demand
response) to also participate in the market and perform the
valuable function of providing capacity and energy resources
without the need for transmission losses (avoided power avoids
transmission of kWH/MWH to the endpoint, therefore freeing up
transmission and distribution lines to carry power elsewhere where
it is needed). It should be noted that most utilities do not have
accurate measurements of distribution losses below their electrical
bus (substation levels) and as such high performance, IP-based
active grid elements and corresponding service points that allow
this information to be brought forward to the utility operations
promote the Operating Reserves and "Negawatts" and add to their
value.
[0184] The following related US patents and patent applications,
U.S. application Ser. No. 13/172,389, filed Jun. 29, 2011, which is
a continuation of U.S. application Ser. No. 12/715,195, filed Mar.
1, 2010, now U.S. Pat. No. 8,032,233, which is a divisional of U.S.
application Ser. No. 11/895,909 filed Aug. 28, 2007, now U.S. Pat.
No. 7,715,951, are incorporated herein by reference in their
entirety. These documents include descriptions of some active load
management within power grids, and provide additional background
and context for the present invention systems and methods.
[0185] Also, in this document, relational terms, such as "first"
and "second," "top" and "bottom," and the like, may be used solely
to distinguish one entity or element from another entity or element
without necessarily requiring or implying any physical or logical
relationship or order between such entities or elements. The terms
"comprises," "comprising," or any other variation thereof are
intended to cover a non-exclusive inclusion, such that a process,
method, article, or apparatus that comprises a list of elements
does not include only those elements, but may include other
elements not expressly listed or inherent to such process, method,
article, or apparatus. The term "plurality of" as used in
connection with any object or action means two or more of such
object or action. A claim element proceeded by the article "a" or
"an" does not, without more constraints, preclude the existence of
additional identical elements in the process, method, article, or
apparatus that includes the element.
[0186] By way of definition and description supporting the claimed
subject matter, preferably, the present invention includes
communication methodologies for messaging via a communication
layer. IP-based communications over a network are most preferred.
Correspondingly, and consistent with the communication
methodologies for messaging according to the present invention, as
used throughout this specification, figures and claims, the term
"ZigBee" refers to any wireless communication protocol adopted by
the Institute of Electronics & Electrical Engineers (IEEE)
according to standard 802.15.4 or any successor standard(s), the
term "Wi-Fi" refers to any communication protocol adopted by the
IEEE under standard 802.11 or any successor standard(s), the term
"WiMax" refers to any communication protocol adopted by the IEEE
under standard 802.16 or any successor standard(s), and the term
"Bluetooth" refers to any short-range communication protocol
implementing IEEE standard 802.15.1 or any successor standard(s).
Additionally or alternatively to WiMax, other communications
protocols may be used, including but not limited to a "1G" wireless
protocol such as analog wireless transmission, first generation
standards based (IEEE, ITU or other recognized world communications
standard), a "2G" standards based protocol such as "EDGE" or "CDMA
2000" also known as "1XRTT", a 3G based standard such as "High
Speed Packet Access (HSPA) or Evolution for Data Only (EVDO), any
accepted 4 G standard such as IEEE, ITU standards that include
WiMax, Long Term Evolution "LTE" and its derivative standards, any
Ethernet solution wireless or wired, or any proprietary wireless or
power line carrier standards that communicate to a client device or
any controllable device that sends and receives an IP-based
message. The term "High Speed Packet Data Access (HSPA)" refers to
any communication protocol adopted by the International
Telecommunication Union (ITU) or another mobile telecommunications
standards body referring to the evolution of the Global System for
Mobile Communications (GSM) standard beyond its third generation
Universal Mobile Telecommunications System (UMTS) protocols. The
term "Long Term Evolution (LTE)" refers to any communication
protocol adopted by the ITU or another mobile telecommunications
standards body referring to the evolution of GSM-based networks to
voice, video and data standards anticipated to be replacement
protocols for HSPA. The term "Code Division Multiple Access (CDMA)
Evolution Date-Optimized (EVDO) Revision A (CDMA EVDO Rev. A)"
refers to the communication protocol adopted by the ITU under
standard number TIA-856 Rev. A.
[0187] It will be appreciated that embodiments of the invention
described herein may be comprised of one or more conventional
processors and unique stored program instructions that control the
one or more processors to implement, in conjunction with certain
non-processor circuits, some, most, or all of the functions for
managing power load distribution and tracking individual subscriber
power consumption and savings in one or more power load management
systems as described herein. The non-processor circuits may
include, but are not limited to, radio receivers, radio
transmitters, antennas, modems, signal drivers, clock circuits,
power source circuits, relays, meters, smart breakers, current
sensors, and user input devices. As such, these functions may be
interpreted as steps of a method to distribute information and
control signals between devices in a power load management system.
Alternatively, some or all functions could be implemented by a
state machine that has no stored program instructions, or in one or
more application specific integrated circuits (ASICs), in which
each function or some combinations of functions are implemented as
custom logic. Of course, a combination of the two approaches could
be used. Thus, methods and means for these functions have been
described herein. Further, it is expected that one of ordinary
skill in the art, notwithstanding possibly significant effort and
many design choices motivated by, for example, available time,
current technology, and economic considerations, when guided by the
concepts and principles disclosed herein, will be readily capable
of generating such software instructions, programs and integrated
circuits (ICs), and appropriately arranging and functionally
integrating such non-processor circuits, without undue
experimentation.
[0188] Recently, the IEEE and ITU have released improved WiMax and
Long Term Evolution wireless standards that have facilitated the
consideration of new technologies to improve the response and
control of power load control devices employing smart breaker and
smart disconnect switches that include advanced smart meters where
IP multimedia gateways are embedded or attach as separate connected
printed circuit boards, and submetering technologies that possess
sufficient "revenue grade" metrology such that the measurements
provided by these devices may be accepted for settlement purposes.
The term "revenue grade" is an industry term, as will be
appreciated by one of ordinary skill in the art, a percentage of
accuracy determined by ANSI, which means that power measurement
must be within 1/2% of the actual value being consumed. Thus,
calibration standards are provided accordingly to OEMs of power
measuring devices and/or chips. In embodiments of the systems and
methods of the present invention, these calibration standards are
met via components, including a chipset and related software, and
the transmittal of the power measurement information via IP-based
communications as set forth hereinabove. Baselining techniques that
provide a reference power usage point, sampling techniques that
allow for verification of the power "state" and power consumption
data for electricity consuming devices (inductive or resistive),
reactive power, Power Factor, start-up current, duty cycles,
voltage, consumption forecasts and most importantly real-time or
near real-time power measurement sampling, etc., are required to
derive a Power Supply Value (PSV) that includes an American
National Standards Institute (ANSI), ISO, grid operator, governing
body revenue measurement, etc., which is preferably aggregated to
reach the size of at least a single Power Trade Block (PTB) unit
for the purposes of optimally monetizing the active load management
from the customer perspective. PTBs are dependent on a grid
operator, regional transmission operator, or independent system
operator to determine the capacity size (in kW or MW) or energy
data in (kWH or MWH) that can be accepted for bidding, trading,
settlement by the utility, the end consumer/customer, the market
participant, the CSP, demand response aggregator or any entity
authorized by the government entity that regulates grid operators
such as FERC, NERC etc. Generally due to measurement, verification,
transmission and/or distribution modeling (which considers the
impact to the grid from the curtailment activities at any geodetic
location on the grid, but generally modeled by electrical bus or
substation), the minimum acceptable PBT is 100 kW at the time of
the present invention. This limitation is not expected to be
permanent, given these advancements in measurement/verification,
the near real time or real time IP/Ethernet based telemetry
capabilities presented by a plurality of various communications
methods as discussed in this embodiment and the advancements in
service oriented architecture based (SOA) software and hardware
subsystems, when combined with an ALD and ALC that can perform at a
sublevel such that the minimum PTB can be determined at the device,
home, building, service point, commercial, industrial, transformer,
feeder, substation, transmission line and any sub-point along the
transmission and distribution feeder system of an electrical grid
as so long as minimum telemetry, measurement, verifications,
validation are met and are capable of being aggregated to a minimum
PTB acceptable to the grid operator, ISO, RTO, BA or any other
increment of grid topography used now or in the future for settling
power block increments by sub-PTB.
[0189] Embodiments of the present invention expand upon and enhance
prior technologies by, among other things, employing WiMax, High
Speed Packet Access (HSPA), Evolution for Data Only (EVDO), both
considered 3.sup.rd generation wireless standards, Long Term
Evolution (LTE), considered at the time of the invention as a "4G"
standard and its derivative standards that are most assuredly to be
introduced during the life of this invention, IEEE 802.11 (X) also
known as "WiFi" and its derivative standards inclusive of "Muliple
Input Multiple Output" (MIMO), as set forth in the communication
methodologies hereinabove, a plurality of proprietary mesh and
point to point communications solutions or any Internet Protocol
(IP)-based load control in a system with the ability to monitor and
measure, in real time or in sufficient time increments to satisfy
the telemetry performance standards as established by the
Government or governing bodies (e.g., National Electric Reliability
Corporation (NERC), Federal Energy Reliability Commission (FERC))
the amount of power deferred, conserved or removed (or carbon,
SO.sub.2, or NO.sub.2 eliminated), such as, by way of example, the
Kyoto or Copenhagen Protocols that set up carbon credits. These
improvements allow new options for electric utilities or any market
participant to defer or invest in new power generation that is
friendlier to the environment.
[0190] The present invention provides the ability to project lost
revenues, and provide actual data to support the projections,
without disadvantaging the consumer, especially residential
consumers of electric power from the grid, for example in the case
of utility wherein the customer is charged any fees associated with
the inefficiency of the network, even where those inefficiencies
may be due to the lack of maintenance or upgrades to the system, or
to natural disasters, or the inability to maintain frequency or
voltage or grid stability in accordance with requirements of FERC,
NERC, etc. The utility was not assessed a NERC financial penalty
for its failure to assure and maintain grid stability and
operations. The prior art smart meter infrastructure with 15-minute
interval data daily cannot settle or transmit the information to
calculate the capacities in the transmission distribution system,
the faults in the system, or the faults of the generation system,
because the smart meter infrastructure provides past data only for
modeling, rather than dynamic modeling, as with the present
invention, wherein the dynamic modeling provides real-time results
to maximize the efficiencies of the system while providing
consumers control over consumption by being able to buy, sell,
trade, exchange, barter, and combinations, with real-time or near
real-time data. So instead of waiting 15 minutes for the next KWP,
the consumer can "check-out" immediately and track spending, just
like with consumer products for tracking any other expenditures,
automated check outs, payments, and statement reviews, as in online
banking.
[0191] The present invention provides for mobile devices used for
updating the PSV, meters, etc., which are also used by consumers
and businesses for real-time review of financial information on
their respective accounts, and for making changes to profiles,
settings, and preferences.
[0192] Pass-through individual coordinators, or linked
coordinators, which are connected and feed into one or more
databases, preferably consider all attributes for curtailment,
supply, profiles, price, etc., and combinations thereof for the
grid elements that communicate with the coordinators. TDSP
subsystems provides for master SCADA information, market (ISO or
vertically integrated) information, that are communicated with the
EMS. Preferably, all systems are linked together with SOA, with a
communications network for sharing data, information, etc.,
preferably Ethernet, according to the present invention. The ISO
and TDSP produce the information for the market, which is
communicated via network to the coordinator(s). The EMS has ICCP
associated with the bus; and the ISO provides for grid stability,
pricing, etc. The TDSP provides for grid health, losses (reported
at the electrical bus). The present invention further provides for
resource settlement nodes associated with the grid resource nodes,
where the generators or supply sources connect to the electrical
power grid. The present invention provides for financial settlement
generating transactions at any grid element attachment point, as
well as, and including the resource settlement nodes. ALD, ASD,
and/or coordinator(s) communicate with the grid elements associated
with supply or generation for the grid, and are all connected, both
in electric power grid transmission and communication network
connection, to a resource node. Grid elements may further include
(but are not limited to) transmission, transformers, end points,
smart meters, attachment points, and combinations. Preferably, all
grid elements have geodetic references associated with them. The
transaction for financial settlement for grid elements occurs at
the supplier and/or consumer points of connection to the grid.
Settlement at the grid elements, in any location associated with
grid element participation in the grid, is provided by the present
invention.
[0193] Outside the electrical bus or substation within the electric
power grid, the financial transaction subsystem provides
information between the subsystems and from the electrical bus to
the market. Since the present invention's settlement processor
provides for clearing of financial settlement data at or less than
15 minute increments, at 15 minute intervals or increments, with
better and more accurate data than with any prior art systems,
customers (or owners of the grid elements participating in the
electric power grid) clear the market with the best price for power
supplied to the grid and also pay less for energy consumed (demand)
from the grid supply. This occurs because inefficiencies are
factored out or reduced in terms of allocation to those grid
elements, control generation, control usage/consumption, make
informed decisions about participation, or based upon profiles,
automatically participate. All information automatically clears and
settles, i.e., the systems and methods of the present invention
automatically provide a financial settlement for each active grid
element for its participation in the electric power grid, to the
grid element owner, with communications through the coordinator and
with settlement through the settlement processor as described
herein and illustrated in FIG. 1.
[0194] By way of contrast to the prior art, wherein inefficiencies
are spread amongst all participants (e.g., the leaks out of the
lakes and pipes), whether they are consuming or supplying, the
present invention systems and methods provide for each of the grid
elements that are registered and participating within the financial
settlement system to have improved accuracy of data relating to
such participation, thereby reducing or eliminating the
inefficiency "spread" losses that would have been associated with
those grid elements under the state of the art distribution. Thus
the present invention provides solutions for the longstanding,
unmet needs of participating grid element owners to supply
empirical data relating to their participation that directly
evidences the specific losses, if any, that are directly related to
their participation. Improved modeling based upon data provided for
less than 15 minute intervals is provided, and eventually, modeling
is eliminated due to the supply of real-time data for actual
participation, rather than assumptions associated with modeling, as
exists in the prior art. So then the inefficiencies are accurately
associated with the loss points and grid elements that function
inefficiently, rather than assuming distribution on a pro-rata
basis to all participating grid elements. Notably, even
nonparticipating grid elements may be assessed for losses and
inefficiencies if they are registered with the grid (e.g., power
consuming customers are assessed a general charge even if they do
not consumer power during a predetermined billing period, which is
generally at 30-day intervals).
[0195] Manual settlement using spreadsheets is still used today;
however, even in the case of manual settlement, the present
invention provides for improved accuracy and timeliness of the
financial settlement of the participation of the grid element.
[0196] Settlement for consumers of electric power of the grid is
considered within the scope of the present invention. Rate plans
include tracking consumption patterns and profiles. Customizable
plans are developed on a per-market-consumer basis under the
present invention systems and methods. So then grid elements
participating in the systems and methods according to the present
invention include electric power consumers having at least one
power consuming device, and at least one registered account
associated with a geodetic location of the at least one power
consuming device.
[0197] The present invention further provides for aggregation of
financial settlement by power consuming devices for a single
consumer. Also and alternatively, classes of customers may be
grouped by "buckets" of consumption that maximize the ability of
consumers to afford the plans they want and for utilities and/or
grid operators to predict and manage the power supplied over the
grid to consumers. By way of comparison, real-time settlements and
customizable plans for electric power consumption for registered
grid elements (and correspondingly, their owners) are provided
similar to mobile telephone rate plans customized or grouped for
consumers having similar patterns, profiles, and/or geographic
locations.
[0198] By way of example, based upon the power supplied, the
reduction in consumed power (curtailment as supply) and/or the
consumption of power, the systems and methods of the present
invention provide for generating at the coordinator a power supply
value (PSV) corresponding thereto by the active grid elements
associated with their participation in the grid. Importantly, the
PSV is an actual value that includes measurement and verification
of the reduction in consumed power; such measurement and
verification methods may be determined by the appropriate governing
body or authority for the electric power grid(s). Power Supply
Value (PSV) is calculated at the meter or submeter, building
control system, or any active grid element that measures power
supplied or consumed within the standard as supplied by the
regulatory body(ies) that govern the regulation of the grid. PSV
variations may depend on operating tolerances, including operating
standards for accuracy of the measurement. The PSV enables
transformation of curtailment or reduction in power, power
supplied, and/or power consumed at the active grid element level by
any system that sends or receives an IP message to be related to or
equated to supply as presented to the governing entity that accepts
these values and awards supply equivalence (e.g., for example of a
power generating entity or an entity allowed to control active grid
elements and their participation on the electric power grid such as
power consuming devices as permitted by the governing body of the
electric power grid, e.g., FERC, NERC, etc.).
[0199] PSV associated with active grid elements and their
participation within the electric power grid may be provided in
units of electrical power flow, monetary equivalent, and/or
combinations thereof. Thus, the PSV provides an actual value that
is confirmed by measurement and/or verification, thereby providing
for supply and/or curtailment value(s) as a requirement for
providing supply to the power grid, wherein the supply to the power
electric power grid is provided for grid stability, voltage
stability, reliability, and combinations thereof, and is further
provided as responsive to an energy management system or equivalent
for providing grid stability, reliability, frequency as determined
by governing authority for the electric power grid and/or grid
operator(s).
[0200] Energy consumption and/or supply patterns associated with
active grid elements and their participation on the electric power
grid are subject to analysis that may be used for a variety of
different types of activities. For example, based on the energy
consumption patterns created from this data, the Coordinator will
derive performance curves and/or data matrices for each service
point to which the active grid elements are attached and determine
the amount of energy reduction that can be realized from each
active grid element and its functionality within the electric power
grid. The Coordinator(s) create a list of service points associated
with the active grid elements and their participation on the
electric power grid through which energy consumption can be reduced
via demand side management, interruptible load, or
spinning/regulation reserves. This information can be manipulated
by the Coordinator and/or ALD processes to create a prioritized,
rotational order of control, called "intelligent load rotation"
which is described in detail below. This rotational shifting of the
burden of the interruptible load has the practical effect of
reducing and flattening the utility load curve while allowing the
serving utility to effectively group its customers within the ALD
or its own databases by energy efficiency.
[0201] Generally, the embodiments described encompass a closed loop
system and method for creating a profile, calculating and deriving
patterns of energy usage and/or supply, and making use of those
patterns when implemented through the machinery of a system
comprised of active grid elements combined with the physical
communications link and when these inputs are manipulated through a
computer, processor, memory, routers and other necessary machines
as those who are skilled in the art would expect to be
utilized.
[0202] The present invention also considers the concept of "drift"
as applied to electric power grids and active grid elements
associated therewith. The data gathered for the active grid element
profile is used to empirically derive the decay rate or drift,
temperature slope, or a dynamic equation (f{x}) whereby the service
point (or device) will have a uniquely derived "fingerprint" or
energy usage pattern for individual and/or aggregated active grid
element(s).
[0203] The embodiments disclosed also make use of the "intelligent
energy rotation" concept. Intelligent energy rotation uses machine
intelligence to ensure that the same active grid elements are not
always selected for energy control events, but distributes energy
supply or load control events over a service area in some equitable
way and/or least cost analysis-applied manner, or other analytical
approach for optimizing the electric power grid resources and
functions of the associated active grid elements registered for
automated intercommunication therewith.
[0204] In another embodiment, energy consumption patterns in active
grid elements profiles are used to identify active grid elements
that are the best targets for excess power sharing. This would
occur when renewable energy such as solar or wind is added to the
grid, resulting in power that cannot be compensated for by the
grid. This could occur, for example, on very windy days. When this
happens, utilities or market participant, grid operator, EMS, or
equivalent are faced with the problem of what to do with the excess
energy. Instead of cutting power to service points in order to
affect power savings, a utility, market participant, grid operator,
EMS, or equivalent could add energy to service points and through
active grid elements associated with those services points in order
to effect power dissipation. The service points and/or active grid
elements selected by the Coordinator may be different (or even the
inverse) of those selected for power savings. The devices at these
service points would be turned on if they were off or set points
for climate-controlled devices would be adjusted to heat or cool
more than normal. Spread out over many control points, this can
provide the energy dissipation needed.
[0205] In a further embodiment, energy consumption patterns within
active grid elements profiles could be used to identify
opportunities for up selling, down selling, or cross selling. These
opportunities may be determined by the power utility or by its
partners. Data from active grid elements profiles and their
participation on the electric power grid may be used to provide
insights on inefficient devices, defective devices, or devices that
require updating to meet current standards. Active grid elements
profiles data, and/or data associated with their participation on
the electric power grid, individually or collectively (or
selectively) in the aggregate, may also be used to identify related
power grid participation opportunities.
[0206] According to the present invention, PSV for any of the
active grid elements and their participation on or within the
electric power grid may be generated by methods including
information relating to baselining historical load, also known as
the customer baseline (CBL), estimating based upon curves,
real-time or near-real-time value, and combinations thereof.
[0207] Advantageously, the present invention provides active load
and/or supply management metrics for each of the active grid
elements, including PSV, much better than merely a statistical
estimate for a command as with prior art; PSV also further provides
for steps of measurement and settlement, according to the present
invention. FERC requires that the settlement credits are provided
at point where settlement occurs; settlement information follows
the transaction, most preferably, according to the present
invention, occurring in real time or near real time, as in
financial transactions or other commodity transactions, such as for
natural gas supply. Also, preferably, there is a defined interval
that is accepted or acceptable by the governing entity for the
electric power grid, wherein each transaction is recorded as it
occurs. Furthermore, the present invention provides for IP
real-time communications that provide for settlement of the
curtailment by load-consuming devices at or approximate to the time
of the transaction, i.e., the curtailment. Also, preferably, there
is participation data for the grid elements that provides
supporting evidence attached with the IP real-time communication of
the acceptance of the power event, and then automatically recorded
in a settlement database and associated with each active grid
elements registered within the system through the Coordinator(s),
and participation on the electric power grid by the grid elements
that are registered with the system. Also, some information related
to this transaction and its settlement is transmitted to the energy
supplier and/or energy/curtailment purchaser, permitting the seller
to be paid according to the PSV and/or PTB related to the power
event, e.g., curtailment or supply event(s).
[0208] Power Trading Blocks (PTBs) are dependent upon the grid
operator or ISO; there must be enough curtailment or supply for the
grid operator to accept, settle, and monetize, including individual
and/or collective or selectively aggregated data for active grid
elements registered with the system and their participation on or
within the electric power grid. At this time, the PTB is 100 KW in
most electric power grids, including a conventional utility,
independent system operator, grid, or microgrid operator.
Generally, the power available as operating reserves is traded in
larger amounts, PTB size, to be significant enough to beneficially
stabilize the grid and its operating reserves. At this time, the
regional trading organization or geographic-specific grid and
corresponding regulations therefor, determine the PTB size, which
typically requires the aggregation of load from a multiplicity of
consumers, residential or commercial, to reach a minimum PTB size
or PTB unit. The PTB unit, combined with the PSV, and the real-time
secure communications used with ALC/ALD function to lower the size
of the minimum PTB required to form a PTB unit for grid reception
and settlement purposes. The commercial impact determines the
minimum PTB size, which corresponds to a PTB unit, due to cost and
timing of communication of the information related to the
curtailment event(s) and response by the device(s), and how
aggregation of load curtailment by the multiplicity of devices is
managed to ensure maximum compensation to the customer(s)
associated with the device(s) for the curtailment event, with
minimum negative physical impact to those consumers and/or devices
from the curtailment event.
[0209] Active grid element profiles and their participation on the
electric power grid may also be dynamic, and settlement processing
associated with those grid elements includes consideration of those
profiles, in addition to the data from participation of the grid
elements for supply and/or curtailment, and for energy consumption
as well. An example of this would be the ability for active grid
elements or grid elements and their participation within the
electric power grid to utilize real time communications from an
electric utility grid, market, market participant, utility, REP,
CSP or any other entity authorized on behalf of the owner to act on
their behalf to control load consuming devices owned by the
consumer and connected to the electric utility grid. Preferably,
the active grid elements receive this information automatically
through a plurality of methods utilizing IP-based communications
methods and web based devices such as smart phones, computers, text
messages, paging messages, or even voice response units or live
customer service agents. Under this real time scenario, active grid
elements could dynamically "Opt In" to a pre-determined profile,
"Opt Out," or, more importantly, change the profile dynamically to
take advantage of real time market pricing of electricity being
sold by the utility, market participant, REP or any entity
authorized to buy, sell and trade electric commodity or demand
response products on behalf of the owner.
[0210] The present invention has adequately described in great
detail how the active grid elements and their participation on the
electric power grid are associated with the Coordinator and the
employment of computer assisted apparatus that include, but are not
limited to processors, ASICS, memory, analytics, communications
interfaces and methodologies, databases, both relational, high
performance "historian" databases, persistence and cache layers,
metadata layers, analytics engines, monitoring and reporting active
grid elements, Internet Protocol, Ethernet, carrier grade wired and
wireless networks, proprietary networks, TDM wireless and wired
networks, analog and digital telemetry subsystems, Coordinators,
Active Supply Directors and a plurality of the above both
centralized, networked together and distributed. While the previous
descriptions have been detailed in the embodiment of a FERC 745
load acting as supply, one skilled in the art will correlate those
functions previously described as they apply to the supply side for
FERC 750 and 755, including settlement.
[0211] These highly decentralized networks must be capable of
operating directly under the control of an EMS/DMS/GMS or similar
control solution, through a Coordinator, and for active grid
elements autonomously if they are disconnected from the macro
electric grid or have voluntarily opted to disconnect themselves
from the electric grid temporarily or permanently. The present
invention provides through software, hardware and advanced
communications methodologies the capabilities of many small
Distributed Electric Resources (DER) associated with the active
grid elements to perform and deliver their energy resource directly
to the electric grid interconnected as if they were a macro
resource with aggregated PSV values that build up to minimum PTB
blocks that can be both presented, operated and monetized by a
Market Participant, REP, Utility, IPP, a Company acting as their
own energy agent or a plurality of all of the above.
[0212] The present invention also provides for intermittent
resources previously described, and the ability of the grid
elements providing supply to the grid to be balanced, regulated and
offered to the grid as reliably as DER. Balancing DER would suggest
that a plurality of these resources may be co-located at the same
service point/attachment or be themselves disaggregated from each
other physically, but interconnected via the present invention and
its attributes. An embodiment of this type of DER would be a
commercial building that has installed solar film, panels or
combinations thereof, a wind or water turbine, and a back-up
generator at the same installation. These different resources with
their different DER attributes must all be combined through an ASC
that would have the capability of providing for primary frequency
control per supply source, voltage control, and meet the
appropriate attachment regulations that may be different based upon
the location of the DER supply on the distribution or transmission
system and operating those systems either through a coordinator and
an EMS or autonomously from both while still offering its supply to
the interconnected electric grid. The present invention functions
to communicate and control the DER based upon availability of the
resource, what the grid's energy needs are at the moment of the
energy being presented by or through a Market Participant or, if
permitted by the governing entity, an individual consumer utilizing
the present invention or the economic incentives that are
profile-based, sold in advance through an approved trading
organization approved by the governing entity, or supplied in real
time at the attachment point on the grid and supplied through the
present invention as directed by an Energy Management System or
providing those EMS services due to an EMS not being available at
the time the resource is delivered and whereby the apparatus of the
present invention is providing energy and grid stabilizing
resources from the available sources, balanced upon what each
resource can provide reliably to the interconnection of the
electric grid.
[0213] Other embodiments of DER that can be used with the present
invention would be communication facilities such as wireless
communications towers owned by carriers, tower leasing companies
such as American Tower, Crown Castle Inc. SBA Inc etc., whereby
standby generation, batteries, solar, wind or other forms of backup
generation including fuel cells are present to insure reliability.
Wireline facilities, such as data centers, central offices, retail
stores, hospitals, fabrication facilities, manufacturing
facilities, service facilities, emergency management facilities,
television facilities, cable facilities, utility facilities, and
other critical infrastructure, are all examples of micro and
macrogrid interconnections whereby latent standby generation and
DER may already be present and whereby the use of the described
invention would be used to interconnect these DER to the electric
power grid as active power devices.
[0214] Transmission and distribution companies are used to estimate
losses, power flow, and power loss models. Modeling is usually
provided by the TDSP/utility; they measure information within the
grid so that they can estimate transmission losses. Transmission
and distribution loss modeling are used in each substation, feeder,
and electrical bus to approximate losses between the transmission
and distribution device and end point where the load is being
served. These models are also used when empirical data is
available; they are industry-accepted practices that provide a
level of engineering safety and capacity factors which are widely
accepted practices. Instead of relying solely on modeling, the
empirical data is used to correct the models. All models have
coefficients of loss that may be improved; the modeling is improved
for all the data provided. Transmission loss models are considered
for frequency, distance, size of cable, etc., and combinations
thereof.
[0215] Generation losses are also a function of the efficiency of
transfer, transformers, resource nodes, etc., and combinations
thereof. The transmission cable age, insulation type, capacitance
and reactive power elements, material age and type, degradation,
bending radius, etc., and combinations thereof are all factors used
in modeling and will also affect the actual empirical measurements
or data. Empirical data is characterizing the distribution
environment so that the modeling is more accurate. Self-correcting
algorithms are employed in the model, which consider the empirical
data relating to the distribution environment, including but not
limited to temperature, humidity, physical environment factors
(e.g., connector/connection, etc.), and combinations.
[0216] Timing for EMS is set by the governing body for frequency
response, reserves, etc. The telemetry is set by industry practice
and governing body(ies) (including NERC, FERC, etc., in USA), and
may vary by geographic location, country, etc. By way of example,
European countries transmit 3-phase power to all endpoints and
service attachment points, including small residential and
commercial accounts, and operate at 50 Hz standards (by way of
contrast and comparison, the USA operates at 60 Hz standards).
[0217] Ability to project lost revenues without disadvantaging the
consumer and making whole transmission and distribution companies,
especially residential consumers of electric power from the grid,
for example in the case of utility wherein the customer is charged
any fees associated with the inefficiency of the network, even
where those inefficiencies may be due to the lack of maintenance or
upgrades to the system, or to natural disasters, or the inability
to maintain frequency or voltage or grid stability in accordance
with requirements of FERC, NERC, etc. The utility was not assessed
a NERC financial penalty for its failure to assure and maintain
grid stability and operations. The prior art smart meter
infrastructure that has a 15-minute interval (or greater) data
daily cannot settle or transmit the information to calculate the
capacities or losses in the transmission or distribution system, or
the faults in the system, or faults of the generation system,
because they provide past data only for modeling, rather than
dynamic modeling, as with the present invention. The present
invention provides modeling as well as real-time results to
maximize the efficiencies of the system while providing consumers
control over consumption by being able to buy, sell, trade,
exchange, barter, and combinations, with real-time or near
real-time data. So instead of waiting 15 minutes for the next KWP,
the present invention allows for near real-time settlement at less
than 15 minute intervals, including the electronic financial
settlement therefor, so that the consumer or supplier for the grid
(provided through at least one active grid element) can "check-out"
immediately and track spending, just like with consumer products
for tracking any other expenditures, and automated check outs,
payments, and statement reviews, as in online banking.
[0218] The present invention provides for mobile devices used for
updating PSV, meter, etc., which are also used by consumers and
businesses for real-time review of financial information on their
respective accounts, make changes to profiles, settings, and
preferences.
[0219] Pass-through individual coordinators, or linked
coordinators, which are connected and feed into one or more
databases, preferably consider all attributes for curtailment,
supply, profiles, price, etc., and combinations thereof for the
grid elements that communicate with the coordinators. TDSP
subsystems provides for master SCADA information, market (ISO or
vertically integrated) information, that are communicated with the
EMS. Preferably, all systems are linked together with SOA, with a
communications network for sharing data, information, etc.,
preferably Ethernet, according to the present invention. The ISO
and TDSP produce the information for the market, which is
communicated via network to the coordinator(s). The EMS has ICCP
associated with the bus; the ISO provides for grid stability,
pricing, etc. The TDSP provides for grid health, losses (reported
at the electrical bus). The present invention further provides for
resource settlement nodes associated with the grid resource nodes,
where the generators or supply sources connect to the electrical
power grid. The present invention provides for financial settlement
generating transactions at any grid element attachment point, as
well as, and including the resource settlement nodes. ALD, ASD,
and/or coordinator(s) communicate with the grid elements associated
with supply or generation for the grid, and all are connected, both
in electric power grid transmission and communication network
connection, to a resource node. Grid elements may further include
(but are not limited to) transmission, transformers, end points,
smart meters, attachment points, and combinations. Preferably, all
grid elements have geodetic references associated with them. The
transaction for financial settlement for grid elements occurs at
the supplier and/or consumer points of connection to the grid.
Settlement at the grid elements, in any location associated with
grid element participation in the grid, is provided by the present
invention.
[0220] Outside the electrical bus or substation within the electric
power grid, the financial transaction subsystem provides
information between the subsystems and from the electrical bus to
the market. Since the present invention's settlement processor
provides for clearing of financial settlement data at or less than
15 minute increments, at 15 minute intervals or increments, with
better and more accurate data than with any prior art systems,
customers (or owners of the grid elements participating in the
electric power grid) clear the market with a better price for power
supplied to the grid and also pay less for energy consumed (demand)
from the grid supply. This occurs because inefficiencies are
factored out or reduced in terms of allocation to those grid
elements, control generation, control usage/consumption, make
informed decisions about participation, or based upon profiles,
automatically participate. All information automatically clears and
settles, i.e., the systems and methods of the present invention
automatically provide a financial settlement for each active grid
element for its participation in the electric power grid, to the
grid element owner, with communications through the coordinator and
with settlement through the settlement processor as described
herein and illustrated in FIG. 1.
[0221] By way of contrast to the prior art, wherein inefficiencies
are spread amongst all participants (e.g., the leaks out of the
lakes and pipes), whether they are consuming or supplying, the
present invention systems and methods provide for each of the grid
elements that are registered and participating within the financial
settlement system to have improved accuracy of data relating to the
participation, thereby reducing or eliminating the inefficiency
"spread" losses that would have been associated with those grid
elements under the state of the art distribution. Thus the present
invention provides solution for the longstanding, unmet needs for
participating grid element owners to supply empirical data relating
to their participation that directly evidences the specific losses,
if any, that are directly related to their participation. Improved
modeling based upon data provided for less than 15 minute intervals
is provided, and eventually, modeling is eliminated due to the
supply of real-time data for actual participation, rather than
assumptions associated with modeling, as exists in the prior art.
So then the inefficiencies are accurately associated with the loss
points and grid elements that function inefficiently, rather than
assuming distribution on a pro-rata basis to all participating grid
elements. Notably, even nonparticipating grid elements may be
assessed for losses and inefficiencies if they are registered with
the grid (e.g., power consuming customers are assessed a general
charge even if they do not consumer power during a predetermined
billing period, which is generally at 30-day intervals).
[0222] Manual settlement using spreadsheets is still used today;
however, even in the case of manual settlement, the present
invention provides for improved accuracy and timeliness of the
financial settlement of the participation of the grid element.
[0223] Settlement for consumers of electric power of the grid is
considered within the scope of the present invention. Rate plans
include tracking consumption patterns and profiles. Customizable
plans are developed on a per-market-consumer basis under the
present invention systems and methods. Thus, grid elements
participating in the systems and methods according to the present
invention include electric power consumers having at least one
power consuming device, and at least one registered account
associated with a geodetic location of the at least one
power-consuming device.
[0224] Aggregation of settlement by power consuming devices for a
single consumer is also provided according to the systems and
methods of the present invention. Also and alternatively, classes
of customers may be grouped by consumption to provide an aggregated
KWP by PTB unit(s) that maximize the ability of the consumers to
afford the plans they want, and for utilities and/or grid operators
to predict and to manage the power supplied over the grid to
consumers. By way of comparison, real-time settlements and
customizable plans for electric power consumption for registered
grid elements (and correspondingly, their owners) are provided
similar to mobile telephone rate plans customized or grouped for
consumers having similar patterns, profiles, and/or geographic
locations.
[0225] It should be noted that many terms and acronyms are used in
this description that are well-defined in the telecommunications
and/or computer networking industries and are well understood by
persons skilled in these arts, and in electric power management
arts. Complete descriptions of these terms and acronyms, whether
defining a telecommunications standard or protocol, can be found in
readily available telecommunications standards and literature and
are not described in more detail herein.
[0226] It will be appreciated that embodiments or components of the
systems described herein may be comprised of one or more
conventional processors and unique stored program instructions that
control the one or more processors to implement, in conjunction
with certain non-processor circuits, some, most, or all of the
functions for managing power load and/or supply distribution, and
tracking and controlling individual subscriber power consumption
and savings, and power supply in one or more power load and/or
supply management systems. The non-processor circuits may include,
but are not limited to, radio receivers, radio transmitters,
antennas, modems, signal drivers, clock circuits, power source
circuits, relays, meters, sub-meters, smart breakers, current
sensors, and customer input devices. As such, these functions may
be interpreted as steps of a method to distribute information and
control signals between devices in a power load and/or supply
management system. Alternatively, some or all functions could be
implemented by a state machine that has no stored program
instructions, or in one or more application specific integrated
circuits (ASICs), in which each function or some combinations of
functions are implemented as custom logic. Of course, a combination
of the two approaches could be used. Thus, methods and means for
these functions have been described herein. Further, it is expected
that one of ordinary skill in the art, notwithstanding possibly
significant effort and many design choices motivated by, for
example, available time, current technology, and economic
considerations, when guided by the concepts and principles
disclosed herein, will be readily capable of generating such
software instructions, programs and integrated circuits (ICs), and
appropriately arranging and functionally integrating such
non-processor circuits, without undue experimentation.
[0227] Additionally, measurement, verification, and settlement for
the PSV for those market participants involved in the power
management of the system is further included in the application of
the present invention. Also, the systems, methods, and apparatus of
the present invention may further include a database, a processor,
software operable thereon, and interfaces to outside market
participants that provide for capacity reservation of the
distribution and transmission systems.
[0228] In embodiments of the present invention, supply and/or load
curtailment as supply active grid elements may further include
additional components to facilitate their automatic registration
with the systems, methods, and apparatus of the present invention.
Furthermore, messaging for registration between these active grid
elements and the Coordinator and/or ASD may include an initial
messaging for the first registration communication that provides
information necessary for activation, operation, and integration
with the electric power grid, including all future messaging,
prioritization, profiles, updates, upgrades, modifications,
settlement, security, and combinations thereof. The Coordinator,
following the initial messaging from the active grid elements, may
optionally provide an "energy cookie" that functions to facilitate
the activities of the Coordinator for management, control,
messaging, and matching to maintain and balance the EMS
requirements with those of the electric power grid and all of the
registered grid elements that are transformed into active grid
elements thereon.
[0229] In the foregoing specification, the present invention has
been described with reference to specific embodiments. However, one
of ordinary skill in the art will appreciate that various
modifications and changes may be made without departing from the
spirit and scope of the present invention as set forth in the
appended claims. For example, the present invention is applicable
for managing the distribution of power from utility companies to
subscribing customers using any number of IP-based or other
communication methods. Additionally, the functions of specific
modules within the server and/or active grid elements may be
performed by one or more equivalent means. Accordingly, the
specification and drawings are to be regarded in an illustrative
rather than a restrictive sense, and all such modifications are
intended to be included within the scope of the present
invention.
[0230] Benefits, other advantages, and solutions to problems have
been described above with regard to specific embodiments of the
present invention. However, the benefits, advantages, solutions to
problems, and any active grid elements that may cause or result in
such benefits, advantages, or solutions to become more pronounced
are not to be construed as a critical, required, or essential
feature or element of any or all the claims. The invention is
defined solely by the appended claims including any amendments made
during the pendency of this application and all equivalents of
those claims as issued.
[0231] Certain modifications and improvements will occur to those
skilled in the art upon a reading of the foregoing description. The
above-mentioned examples are provided to serve the purpose of
clarifying the aspects of the invention and it will be apparent to
one skilled in the art that they do not serve to limit the scope of
the invention. All modifications and improvements have been deleted
herein for the sake of conciseness and readability but are properly
within the scope of the present invention.
* * * * *
References