Construct to mitigate power system operational impacts of emerging “disruptive technologies”
A process/method is provided for the management of electric distribution system operations, including accurate and efficient communications and interfaces between the transmission, distribution and residential distribution systems, managed by a distribution system operator responsible for energy balance and reliability through control on a local distribution area, namely between end use customers and the transmission node of the electrical system.
1. A method for managing distribution system operations, said method comprising operating the distribution system operations on several time horizons, including a pre-operational timeframe, operational timeframe and a post-operational timeframe including the following steps:
a. Receiving DR/DER asset registration information;
b. Receiving distribution capacity limits from a utility;
c. Receiving opt-in/opt-out data;
d. Receiving bilateral DR-DER schedules and ancillary service quantities from DSO Market Participants;
e. Receiving bids and offers from DSO market participants;
f. Receiving DA LMPs from an ISO/RTO;
g. Receiving information regarding DR and DER cleared schedules from an ISO/RTO;
h. Sending notifications regarding forecast distribution bottleneck limits and anticipated limit violations to a utility;
i. Sending information regarding energy and ancillary services available from DR/DER to ISO/RTO markets;
j. Sending information regarding DR and DER cleared schedules to Market Participants and
wherein the operational timeframe, the distribution system operations will update distribution grid topology, update forecasts and operating requirements, and will receive updated schedules, bids and offers from market participants, and updated residual energy and ancillary service requirements from the ISO/RTO.
2. The method of claim 1 , further comprising receiving DR-DER availability forecasts from a DR provider.
3. The method of claim 1 , further comprising calculating DR-DER availability forecasts based on said asset registration information.
4. The method of claim 1 , wherein said opt-in/opt-out data are received from prosumers.
5. The method of claim 1 , wherein said opt-in/opt-out data are received from a utility or other service provider.
6. The method of claim 1 , wherein at least some of the information received or sent is updated for real-time operations.
7. The method of claim 6 , wherein at least some of the information updated is updated by receiving asset telemetry data.
8. The method of claim 6 , further comprising receiving dispatch instructions from a distribution operations center.
9. The method of claim 8 , wherein said dispatch instructions are instructions for aggregated resources.
10. The method of claim 8 , further comprising communicating said dispatch instructions to participants.
11. The method of claim 10 , wherein said dispatch instructions are sent directly to participants' assets in the form of control commands.
12. The method of claim 6 , further comprising sending distribution marginal prices to DSO market participants.
13. The method of claim 12 , wherein said marginal prices are sent directly to DSO market participants' assets.
14. The method of claim 1 , further comprising receiving interval metered data relating to scheduled assets or resources.
15. The method of claim 1 , further comprising receiving settlement statements for products and services from an ISO/RTO.
16. The method of claim 15 , further comprising sending settlement statements to DSO market participants.
17. The method of claim 16 , wherein said settlement statements include charges and credits.
18. The method of claim 1 , further comprising receiving disputes from market participants.
19. A method for managing distribution system operations, and operating the distribution system operations on several time horizons, including a pre-operational timeframe, operational timeframe and a post-operational timeframe including, said method comprising the following steps:
a. Receiving DR/DER asset registration information;
b. Receiving distribution capacity limits from a utility;
c. Receiving opt-in/opt-out data;
d. Receiving bilateral DR-DER schedules and ancillary service quantities from DSO Market Participants;
e. Receiving bids and offers from DSO market participants;
f. Receiving DA LMPs from an ISO/RTO;
g. Receiving information regarding DR and DER cleared schedules from an ISO/RTO;
h. Sending notifications regarding forecast distribution bottleneck limits and anticipated limit violations to a utility;
i. Sending information regarding energy and ancillary services available from DR/DER to ISO/RTO markets;
j. Sending information regarding DR and DER cleared schedules to Market Participants, and
wherein in the pre-operations timeframe, the distribution system operations will determine available ancillary services, and will send information regarding DR/DER cleared schedules, send market information, including prices and forecasts to market participants for operation planning and scheduling.