Performing Real Time Price Auction

Transcription

1 and Margaret Performing Real Time Price Auction "Acknowledgment: This material is based upon work supported by the Department of Energy under Award Number DE-OE " Disclaimer: "This report was prepared as an account of work sponsored by an agency of the United States Government. Neither the United States Government nor any agency thereof, nor any of their employees, makes any warranty, express or implied, or assumes any legal liability or responsibility for the accuracy, completeness, or usefulness of any information, apparatus, product, or process disclosed, or represents that its use would not infringe privately owned rights. Reference herein to any specific commercial product, process, or service by trade name, trademark, manufacturer, or otherwise does not necessarily constitute or imply its endorsement, recommendation, or favoring by the United States Government or any agency thereof. The views and opinions of authors expressed herein do not necessarily state or reflect those of the United States Government or any agency thereof." Version History Rev. Date Author Change description A 06/14/2011 Initial Release B 07/21/2011 First revision C 08/08/2011 AEP workshop Various updates D 9/12/2011 Tim Simmons Implement various updates E 10/13/2011 Brian D. Green Add Narrative, Interface Diagram and updated Actors and steps F 10/20/2011 Barry Peirce Minor word changes and added comments. Changes tracked. Copyright 2011 American Electric Power Company

2 and Margaret Summary: This use case addresses the process of computing the Real Time Price (RTP) signals for the Smart Grid Dispatch. Narrative: Studies indicate that customers who understand the cost of electricity reduce their usage, especially when prices are high. The RTP system (real-time pricing system) will produce price signals every 5 minutes and will communicate this via the internet to every RTP customer and to the HEM at the customer premise. In order to produce this price signal, the Smart Grid Dispatch system (SGD) will take its inputs from many existing systems, including the Home Energy Management (HEM)s The Regional Transmission Organization (RTO) will provide real-time and day-ahead pricing data that will be interfaced to the Billing Costing Engine (BCE). BCE calculates the utility margins and sends the new pricing signals to the SGD.The Distribution Management system (DMS) is interfaced to the SGD in order to provide data regarding the state of the distribution electric network in-scope of the RTP program. The SGD will obtain demand, energy usage and bid data from the HEMs, The SGD will take these inputs and calculate a Market Clearing Price for each distribution Feeder within the RTP program. Page 2 of 13 Copyright 2011 American Electric Power Company Rev. 9

3 Interface Diagram: and Margaret Market Operations RTO 86 Billing Costing Engine Smart Grid Dispatch 22 DMS 88 Internet 57 Smart Meter 9 HEM Customer Note(s): The NIC, ESI and Meter Metrology Board are part of the Smart Meter. Page 3 of 13 Copyright 2011 American Electric Power Company Rev. 9

4 Actor(s): and Margaret The list of the actors and the roles that are participating in this use case described in the table below. Name BCE DMS ESI HEM Meter Metrology Board NIC RTO SGD Role description Billing Costing Engine. Receives pricing signals from the RTO and calculates the Utility margins and sends the new price to the SGD. Distribution Management System HAN network interface component with NIC within the Smart Meter Home Energy Management system (aka Customer EMS) The board, internal to the smart meter, on which the functions of the Smart Meter are configured and performed. AMI network interface component with Meter Metrology Board within the Smart Meter. Regional Transmission Operator in charge of bulk electricity markets (such as PJM) The Smart Grid Dispatch System is the central system within the realtime pricing Page 4 of 13 Copyright 2011 American Electric Power Company Rev. 9

5 and Margaret Participating Business Functions: The participating business function, its acronym and what they provide in this use case are detailed in the table below. Acronym Business Function/Abstract Component Services or Information Provided DMS HEM RTO SGD Distribution Management System (includes input from the following Transmission SCADA, PowerFlow Module), provides distribution circuit loading and calculates congestion on distribution circuits. Home Energy Management system. A logical or physical device typically located at the customer facility that acts as a home electricity control center. As referred to as Customer EMS. Regional Transmission Operator. Operates the bulk electricity market. Smart Grid Dispatch System. The central system for Real-Time (customer) pricing. Provides feeder congestion information to the SGD. The HEM provides the customer HAN Device health state, and the premise profile of 5 minute energy usage (unverified). Provides day-ahead bulk power price schedules and 5 minute Real-Time (bulk) price. System that computes the Real-Time (customer) price signal for utility smart grid operations. Assumptions / Design Considerations: Standard International Electrotechnical Commission (IEC) Message Definition format will be followed to provide the Header, Request, Reply, and payload used when defining the messages for the design specifications. For the purpose of the use cases identified in this document these have been omitted as they are to be provided in the design specification for the Real Time Price Auction use case. This use case describes the RTP computational phase of the RTP auction process. Assumptions on triggering and message patterns: o Each HEM sends its then-current demand, energy usage e.g. meter reading and energy bid to the SGD every five minutes. o The RTO calculates an adjustment to the day ahead price on a periodic basis and publishes the price adjustment to the BCE. o The SGD five minute timer is the trigger for the rest of the real time price calculation process. Upon this periodic trigger, the following occurs: Page 5 of 13 Copyright 2011 American Electric Power Company Rev. 9

6 and Margaret The SGD requests the current distribution system utilization for each feeder from the DMS. This utilization is processed into a DMS price increment for each feeder, to adjust the retail price. Normal Sequence: The sequences of events, showing the order in which they occur during the typical progression of this use case are provided in the table below. The Sequence Diagram that graphically depicts the events is presented immediately following the table. Use Case Step Triggering Event Description Of Process Information To Be Exchanged Producer Receiver Message Type 1 HEM timer periodic trigger HEM timer triggers computation of the Current demand and energy Usage 2 HEM sends on-demand meter read request to ESI 3 ESI sends on-demand meter read request to NIC 4 NIC relays the On Demand Read Request to the Meter Metrology Board 5 On Demand Read Request received Meter Metrology Board retrieves Meter Read in formatted table and sends to NIC 6 NIC sends Meter Read in formatted table from the request to ESI 7 ESI sends Meter Read in formatted table from request to HEM Current Demand & Energy Usage On-demand meter read request On-demand meter read request On Demand Meter Read Request (ANSI C12.19 Table Data) On Demand Meter Read response (ANSI C12.19 Table Data) Meter Read in formatted table Meter Read in formatted table HEM Internal HEM ESI SEP 1.0 ESI NIC Proprietary NIC Meter Metrolog y Board Meter Metrolog y Board NIC read ANSI C12.19 Table Data read-ansi response C12.19 Table Data NIC ESI Proprietary ESI HEM SEP 1.0 Page 6 of 13 Copyright 2011 American Electric Power Company Rev. 9

7 and Margaret Use Case Step Triggering Event Description Of Process Information To Be Exchanged Producer Receiver Message Type 8 HEM sends the Current Demand and Energy Usage and bid to the SGD via the Internet 9 Internet routes the Current Demand and Energy Usage and bid to the SGD 10 RTO new day ahead pricing RTO sends the. Updated Real Time Price (aka day ahead) 11 RTO sends Updated Real Time Price To BCE 12 BCE uses the Updated Real Time Price to calculate the Current Utility RTP 13 BCE sends the Current Utility RTP to the SGD 14 Distribution Circuit Congestion Data update SGD receives Current Distribution Circuit Congestion from DMS 15 SGD calculates the Market Clearing Price for each Feeder Current Demand & Energy Usage & Bid Current Demand & Energy Usage & Bid Updated Real Time Price Updated Real Time Price Current Utility RTP Current Utility RTP Current Distribution Circuit Congestion Market Clearing Price for each Feeder HEM Internet Create /MeterReading Create /SDPLocation DemandBid Internet SGD Create /MeterReading Create /SDPLocation DemandBid RTO Internal Create /PriceNotificati on RTO BCE Create /PriceNotificati on BCE Internal Create /PriceNotificati on BCE SGD Create /PriceNotificati on DMS SGD Create /DistributionUti lization SGD Internal Page 7 of 13 Copyright 2011 American Electric Power Company Rev. 9

8 and Margaret Page 8 of 13 Copyright 2011 American Electric Power Company Rev. 9

9 Integration Scenarios: and Margaret Adapters will use the Common Information Model (CIM) in Extensible Markup Language (XML) to send and receive messages and events. The following are the points of integration that must be tested for this use case. Other non-cim message interfaces may be testable in this use case. Actor Interface Points SGD HEM DMS BCE BCE RTO Pre-conditions: None Post-conditions: None Exceptions / Alternate Sequences: There are no exceptions, unusual events or alternate sequences defined for this use case. Use Case Step Triggering Event Description Of Process Information To Be Exchanged Producer Receiver Message Type Page 9 of 13 Copyright 2011 American Electric Power Company Rev. 9

10 Message Type(s) Diagram: and Margaret The following XML Schema Definition (XSD) diagram shows the normative and informative parts of the message. Not all of the International Electrotechnical Commission s (IEC) CIM message optional elements must or will be used in the use of IEC CIM for this specific use case. SDPLocationDemandBid: Page 10 of 13 Copyright 2011 American Electric Power Company Rev. 9

11 PriceNotification: and Margaret DistributionUtilization: Page 11 of 13 Copyright 2011 American Electric Power Company Rev. 9

12 MeterReading: and Margaret Page 12 of 13 Copyright 2011 American Electric Power Company Rev. 9

13 and Margaret References: Use Cases or other documentation referenced by this use case include: AEP Ohio Interoperability Plan V1.docx: Section (Use Case Real- Time Pricing) Use Cases EPRI Report_V.docx: Section 2.1(Real-Time Pricing) 61968_9_MeterReadingAndControl_FDIS final.docx Message Schemas, UML and other data from the AEP-SISCO-UISOL RTP Workshop Issues: None ID Description Status Miscellaneous Notes: None Page 13 of 13 Copyright 2011 American Electric Power Company Rev. 9