# US 12,191,669 B2 · Distributed energy resources communications network and control system

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- Number: US 12,191,669 B2
- Document ID: US12191669B2
- Status: Granted
- Kind: B2
- Application number: 17/488,550
- Filed: 2021-09-29
- Published: 2022-03-31
- Granted: 2025-01-07
- Earliest claimed: 2020-09-29
- Assignees: GridEdge Networks, Inc.
- Applicants: GridEdge Networks, Inc.
- Inventors: Nachum Sadan; Bruce Renz
- Web page: https://patentgrep.com/patent/US12191669B2

## CPC

- H02J 3/381: {Dispersed generators}
- H02J 3/466: Scheduling or selectively controlling the operation of the generators or sources, e.g. connecting or disconnecting generators to meet a demand
- H02J 13/1331: {using wireless data transmission}
- H04B 3/20: Reducing echo effects or singing; Opening or closing transmitting path; Conditioning for transmission in one direction or the other
- H02J 2103/30: Simulating, planning, modelling, reliability check or computer assisted design [CAD] of electric power networks
- H02J 2103/35: Grid-level management of power transmission or distribution systems, e.g. load flow analysis or active network management
- Y02E 40/70: Smart grids as climate change mitigation technology in the energy generation sector
- Y02E 60/00: Enabling technologies; Technologies with a potential or indirect contribution to GHG emissions mitigation
- Y04S 10/12: Monitoring or controlling equipment for energy generation units, e.g. distributed energy generation [DER] or load-side generation
- Y04S 10/16: Electric power substations
- Y04S 40/126: using wireless data transmission
- H02J: ELECTRIC POWER NETWORKS; CIRCUIT ARRANGEMENTS OR SYSTEMS FOR SUPPLYING OR DISTRIBUTING ELECTRIC POWER; SYSTEMS FOR STORING ELECTRIC ENERGY
- H04B: TRANSMISSION
- Y02E: REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
- Y04S: SYSTEMS INTEGRATING TECHNOLOGIES RELATED TO POWER NETWORK OPERATION, COMMUNICATION OR INFORMATION TECHNOLOGIES FOR IMPROVING THE ELECTRICAL POWER GENERATION, TRANSMISSION, DISTRIBUTION, MANAGEMENT OR USAGE, i.e. SMART GRIDS

## Abstract

A method and system are provided for a distributed communications and control network that manages Distributed Energy Resources (“DER”) on a power utility grid. An integrated network and system uses a hub and spoke, substation-centric network architecture, and comprises: a plurality of edge DER (“E-DERM”) devices, each E-DERM device located at a DER point of interconnection; a single substation DER controller (“D-DERM”) located at a utility substation and configured to manage the plurality of E-DERM devices; integrated point-to-point secured communications between the D-DERM and each of the plurality of E-DERM devices using dual-channel, redundant paths; and closed-loop control software algorithms running autonomously on the D-DERM at the utility substation to monitor and control DER connected to power lines emanating from the utility substation.

## Claims

### Claim 1

An integrated network and system for distributed communications and control of Distributed Energy Resources (“DER”) on a power utility grid, using a hub and spoke, substation-centric network architecture, and comprising:
a plurality of edge DER (“E-DERM”) devices, each E-DERM device located at a DER point of interconnection;
a single substation DER controller (“D-DERM”) located at a utility substation and configured to manage the plurality of E-DERM devices;
integrated point-to-point secured communications between the D-DERM and each of the plurality of E-DERM devices using dual-channel, redundant paths; and
closed-loop control software algorithms running autonomously on the D-DERM at the utility substation to monitor and control DER connected to power lines emanating from the utility substation.

### Claim 2 (depends on 1)

A network and system according to claim 1, wherein the closed-loop control software algorithms comprise a main control loop for each substation, including,
a) for each DER, inputting to one of the plurality of E-DERM devices, real time generation (PGn: output power in Watts) and sending the input to the D-DERM;
b) inputting to the D-DERM, real time power outflow from a station (PS);
c) calculating in the D-DERM the total Load (PS+PG1+PG2+ . . . );
d) comparing Generation to Load (G/L) ratio to factor K (K=0.77);
e) if G/L is greater than K, proceeding to curtail DER output power by 10%, and if G/L is not greater than K, going to step a);
f) sending from the D-DERM a power curtailment command to DER via one of the plurality of E-DERM devices;
g) waiting T seconds, wherein T=1;
h) sending a configuration information request command to curtailed DER;
i) verifying that DER changed its maximum output power limit to 90% of previous value; and if DER didn't change its value, tripping the DER;
j) entering new limit in a local D-DERM data base;
k) waiting L seconds, wherein L=5;
l) going to step a); and
m) ending the control loop.

### Claim 3 (depends on 1)

A network and system according to claim 1, the network and system being configured to manage multiple DER on a utility network where the single D-DERM controls the plurality of E-DERM devices and additional E-DERM devices can be added as needed per utility substation, and further comprising a distributed networked architecture as shown in FIG. 2 for adding further D-DERM controllers in new utility substations that can be installed incrementally.

### Claim 4 (depends on 1)

A network and system according to claim 1, further comprising an uplink connection between the D-DERM in the utility substation and a centralized management system (“C-DERM”) located in a utility control center over a SCADA connection, and wherein the D-DERM sends alarms and alert notifications to the C-DERM and receives DER commands from the C-DERM.

### Claim 5 (depends on 1)

A network and system according to claim 1, configured to enable flexible interconnections of DER and dynamic grid support applications in DER smart inverter functions via direct point to point communications over dual channel private connections, as shown in FIG. 3, and wherein each closed loop control algorithm corresponds to a specific grid use case.

### Claim 6 (depends on 1)

A network and system according to claim 1, wherein the closed-loop control software algorithms monitor and manage station generation/load ratio in real time as shown in FIG. 5; and wherein the closed-loop control software algorithms are implemented in a D-DERM substation controller.

### Claim 7 (depends on 1)

A network and system according to claim 1, wherein the closed-loop control software algorithms are configured to: avoid substation transformer back-feed into a utility transmission system and expanded to optimize circuit hosting capacity and enable other grid support applications.

### Claim 8 (depends on 1)

A network and system according to claim 1, the network and system being used for front of meter and behind the meter DER applications, wherein the plurality of E-DERM devices connect to sources and loads which can then be managed by the closed loop control software algorithms as shown in FIG. 5 directly or through aggregators.

### Claim 9 (depends on 1)

A network and system according to claim 1, wherein the network and system is integrated with DER and non-DER utility assets for grid management applications and is running grid optimization closed loop control algorithms.

### Claim 10 (depends on 1)

A network and system according to claim 1, wherein the closed-loop control software algorithms are configured to provide DER voltage and thermal control as follows:
a) thermal issues only:
current flow in thermally vulnerable elements is continuously monitored once per minute:
when the flow in a monitored element is within 5% of its seasonal thermal limit, reduce by 10% a participating DER output to determine if the vulnerable element's current drops as a result,
if no drop has resulted, the DER is not causing an overload,
return DER output to previous level
if drop has occurred, is the change sufficient (current flow down to 85% of maximum current rating),
if yes, hold DER output at this value,
if no, continue reducing DER output using 10% steps in one-minute intervals until element's current is acceptable or DER output is zero,
when the element's current drops to 80% of seasonal rating, increase DER output until 90% of element rating is reached;
b) overvoltage issues only:
voltages at locations of concern are continuously monitored every 10 seconds:
control action is initiated when voltages at locations of concern are within 1% of upper limits,
for overvoltage at DER terminal, initiate Volt/Var control,
if successful, proceed no further,
if not, continue reducing DER output by 10% in 10 second intervals until voltage is acceptable or DER output is zero,
when voltage is at rated value or below, increase DER output until voltage is within 2% of limit,
for overvoltage remote from DER, reduce by 10% participating DER output to
determine if the remote overvoltage drops as a result,
if it has not dropped, return DER to previous output,
if it has dropped, is the change sufficient,
if yes, hold DER output at this value,
if no, continue reducing DER output by 10% in 10 second intervals until remote voltage is acceptable or DER output is zero,
when voltage is at rated value or below, increase DER output until voltage is within 2% of limit;
c) thermal and overvoltage issues:
voltage and current at sensitive locations are continuously monitored at 10 and 60 second intervals respectively:
when the flow in a monitored element is within 5% of its seasonal thermal limit,
reduce by 10% the participating DER output to determine if the vulnerable element's current drops as a result,
if no drop has resulted, the DER is not causing the overload,
return DER output to previous level,
if it has dropped, is the change sufficient and are all monitored voltages acceptable,
if yes, hold DER output at this value,
if no, continue reducing DER output using 10% steps in one-minute intervals until element's current and all monitored voltages are acceptable or DER output is zero,
when element's current drops to 80% of seasonal rating, increase DER output until 90% of element rating is reached,
when voltages at locations of concern are within 1% of upper limit,
for overvoltage at DER terminal, initiate Volt/Var control,
if successful, proceed no further,
if not, continue reducing DER output by 10% in 10 second intervals until remote voltage is acceptable or DER output is zero and no thermal issues are detected,
when voltage is at rated value or below, increase DER output until voltage is within 2% of limit and no thermal issues are detected,
for overvoltage remote from DER, reduce by 10% participating DER output to determine if the remote overvoltage drops as a result,
if it has not dropped, return DER to previous output,
if it has dropped, is the change sufficient,
if yes, hold DER output at this value,
if no, continue reducing DER output by 10% in 10 second intervals until remote voltage is acceptable or DER output is zero and no thermal issues are detected,
when voltage drops to rated value, increase DER output until voltage is within 2% of limit and no thermal issues are detected.

### Claim 11

An integrated network and system for distributed communications and control of Distributed Energy Resources (“DER”) on a power utility grid, using a hub and spoke, substation-centric network architecture, with integrated point to point communications and comprising:
a plurality of edge DER (“E-DERM”) devices, each E-DERM device located at a DER point of interconnection;
a single substation DER controller (“D-DERM”) located at a utility substation and configured to manage the plurality of E-DERM devices;
integrated point-to-point secured communications between the D-DERM and each of the plurality of E-DERM devices using dual channel redundant paths;
closed-loop control software algorithms running autonomously on the D-DERM at the utility substation to monitor and control DER connected to power lines emanating from the utility substation; and
a Distributed Generation Permissive (“DGP”) system using powerline conducted permissive signal technology as shown in FIG. 4, for sending DGP commands over a powerline.

### Claim 12 (depends on 11)

A network and system according to claim 11, wherein the closed-loop control software algorithms comprise the following control algorithm shown in FIG. 6, wherein the integrated system provides unintentional islanding protection and uses one-way supervisory channel to limit generation to load (G/L) ratio, using nameplate generation data rather than actual real time generation, and wherein permissive commands are embedded within a DGP command, and where for each DER, the D-DERM is configured to:
a) storing all DER nameplate information in a D-DERM database;
b) calculating approximate total station generation using a sum of DER nameplate information;
c) calculating approximate station load using the sum of DER nameplate information and real time station outflow readings;
d) calculating approximate station generation/load ratio (R) using results from prior calculations;
e) comparing R to allowable limit K;
f) establishing control link with DER by
sending a permissive signal when DER is allowed to export power;
stopping the permissive signal when DER is not permitted to export power; and
sending a digitally encoded token to the E-DERM to enable sending a command to the DER;
g) if R>K, sending a digitally encoded token to an appropriate E-DERM device to curtail output power by 10%;
h) if station outflow does not immediately increase due to DER curtailment, disconnecting the DER from the grid by stopping the permissive signal;
i) if station outflow increases, entering new curtailed generation value into D-DERM data base, replacing previous value;
j) going back to the step of calculating approximate total station generation step b); and
k) ending control loop.

### Claim 13 (depends on 11)

A network and system according to claim 11, wherein the closed-loop control software algorithms comprise the algorithm shown in FIG. 5, providing unintentional islanding protection, along with multiple DER grid support applications, thereby providing an all-in-one solution for grid optimization where DER commands are embedded within the DGP signal.

### Claim 14 (depends on 11)

A network and system according to claim 11, wherein the closed-loop control software algorithms comprise a main control loop for each substation, including,
for each DER,
a) inputting to one of the plurality of E-DERM devices, real time DER generation (PGn: output power in Watts) and
b) sending the input to the D-DERM;
c) inputting to the D-DERM, real time power outflow from a station (PS);
d) calculating in the D-DERM the total Load (PS+PG1+PG2+ . . . );
e) comparing Generation the Load (G/L) ratio to factor K (K=0.77);
f) if G/L is greater than K, proceeding to curtail DER output power by 10%, and if G/L is not greater thank K, returning to the prior inputting step a);
g) sending from the D-DERM a power curtailment command to DER via one of the plurality of E-DERM devices;
h) waiting T seconds, wherein T=1;
i) sending a configuration information request command to curtailed DER;
j) verifying that DER changed its maximum output power limit to 90% of previous value; and if DER didn't change its value, tripping the DER;
k) entering a new limit in a local D-DERM data base;
l) waiting L seconds, wherein L=5;
m) returning to the prior inputting step a); and
n) ending the control loop.

### Claim 15 (depends on 11)

A network and system according to claim 11, the network and system being configured to manage multiple DER on a utility network where the single D-DERM controls the plurality of E-DERM devices and additional E-DERM devices can be added as needed per utility substation, and further comprising a distributed networked architecture as shown in FIG. 2 for adding further D-DERM controllers in new utility substations that can be installed incrementally.

### Claim 16 (depends on 11)

A network and system according to claim 11, further comprising an uplink connection between the D-DERM in the utility substation and a centralized management system (“C-DERM”) located in a utility control center over a SCADA connection, and wherein the D-DERM sends alarms and alert notifications to the C-DERM and receives DER commands from the C-DERM.

### Claim 17 (depends on 11)

A network and system according to claim 11, configured to enable flexible interconnections of DER and dynamic grid support applications in DER smart inverter functions via direct point to point communications over dual channel connections, as shown in FIG. 3, and wherein each closed loop control algorithm corresponds to a specific grid use case.

### Claim 18 (depends on 11)

A network and system according to claim 11, wherein the closed-loop control software algorithms are configured to avoid substation transformer back-feed into a utility transmission system and expanded to optimize circuit hosting capacity and enable other grid support applications.

### Claim 19 (depends on 11)

A network and system according to claim 11, the network and system being used for front of meter and behind the meter DER applications, wherein the plurality of E-DERM devices connect to sources and loads which can then be managed by the closed loop control software algorithms as shown in FIG. 5 directly or through aggregators.

### Claim 20 (depends on 11)

A network and system according to claim 11, wherein the network and system is integrated with DER and non-DER utility assets for grid management applications and running grid optimization closed loop control algorithms.