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SMD

SMD. Generator Operator Forum. Date: November 6, 2002 Presented by: John Norden. Before we begin. Logistics Introduce ISO Staff Purpose Presentation Feedback. Agenda Customer Forum - System Operations Under SMD Wednesday, November 6, 2002, 12:30 - 4:30 p.m. Purpose:

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SMD

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  1. SMD Generator Operator Forum Date: November 6, 2002 Presented by: John Norden

  2. Before we begin... • Logistics • Introduce ISO Staff • Purpose • Presentation • Feedback

  3. Agenda Customer Forum - System Operations Under SMD Wednesday, November 6, 2002, 12:30 - 4:30 p.m. Purpose: Discuss the operational changes to the commitment and dispatch of generators under Standard Market Design (SMD) Discuss changes to the information and format of data presented to the RIGS under SMD 12:30 - 1:30 Working Lunch 1:00 – 1:10 Welcome, Introductions, Ground rules – Paul Liepe 1:10 – 3:00 SMD Changes for Generation & Information Supplied via RIGS - John Norden 3:00 – 3:15 Break 3:15 – 4:00 Technical Changes to RIGs and Data – Paul Knaplund 4:00 – 4:20 Questions & Answers - Panel 4:20 – 4:30 Wrap-up – Paul Liepe 4:45 Meeting Ends Panelists: Joe Mercer, Kevin Seliga, Ron Coutu, Jim Milligan, Don Gates, Greg Stoltzfus

  4. SMD Generator Operator Forum1) Changes for Generators 2) Suggested RIG Information

  5. Section objectives • Overview of topics for SMD changes for Generators • Unit Control Modes • Startup/Shutdown Instructions • Start-up Profile • Fast Start Communications • Self-Schedule Changes • Response Rates • Autocall • Limited Energy Generator • Overview suggested information to be supplied via RIGs • Receive feedback on RIG changes

  6. Overview: ISO Responsibilities ISO New England System Operators are responsible for: • Maintaining system security and reliability • Monitoring the operation of the electronic dispatch • Monitoring units NOT on electronic dispatch • Logging System Operator actions • Controlling the system during abnormal generation and transmission contingency events

  7. Overview: Participant Responsibilities • The Lead Participants or Designated Entities are responsible for submitting their Offer Data and Supply Offer information. • Offers and resource characteristics are submitted for the following specific services: Energy and Regulation. In the initial stages of SMD there will be no Reserve Market. • Each dispatchable unit that participates in the NEPOOL real-time Market will receive DDPs from ISO New England throughtheir Designated Entity via the RIGs.

  8. 12 > 16 18 22 00 < Overview: SMD Operations Timeline DAM Re-Offer RAA Operating Day 5-Submit Regulation Offers 7-Submit reoffers for units not committed in DAM 9-Submit redeclarations 11-Submit start-up profiles if desired 13-Request to bind LEG schedule in real-time 15-Submit redeclared hourly LEG maximums 20-Provide start-up profiles upon request 1-Submit Generation Offers for Energy and Regulation 22-Confirm unit startups 24-Respond to Dispatch Instructions 25-Notify ISO of startup/ shutdown and redeclarations DE/ LP 2-Receive Generation Offers for Energy and Regulation 3-Create DAM Schedule 4- Post DAM Schedule to eMarket 6-Receive Regulation Offers 8-Receive reoffers for units not committed in DAM 10-Receive redeclarations 12-Receive start-up profiles 14-Per DE request, set LEG schedule to bind 16-Receive redeclared hourly LEG maximums 17-Perform Reserve Adequacy Assessment to meet Load Forecast and Reserves 18-Perform Regulation Optimization to ensure sufficient Regulation capacity online 19-Request start-up profiles for any additional commitment 21- Call out/ confirm unit startups 23-Provide Dispatch Instructions 26-Receive redeclarations 27-Provide startup/ shutdown instructions ISO Market Administration Forecast Control Room

  9. Overview: Nomenclature Change Summary

  10. Overview: Unit Control Modes (1 of 2) The Unit Control Modes (UCMs) for SMD will be the following: • UCM 1 – Units that have tripped off-line, out-of-service or are off-line and not meeting scheduled output even if no physical problem exists • UCM 2 – Units that are off-line and available for dispatch • UCM 3 – Units that are online but not dispatchable • UCM 4 – Units that are on-line and available for dispatch

  11. Overview: Unit Control Modes (2 of 2) • UCM 5 – Units that are being postured by the ISO. This applies to online units being operated out of merit to conserve Energy for future dispatch or provide current Operating Reserve. Units that are already offline or shutdown per ISO request can also be postured, they will remain in UCM 2 and their postured status recorded in the ISO Control Room Event Log and flagged in the EMS. • UCM 6 – Units that are regulating • UCM 7 – Unit that are synchronous condensing. Only units that have submitted offers in this category will be eligible for this mode.

  12. Overview: Startup Instructions • Following the completion of the Day-Ahead market at 1600, the Participant is expected to view the Day-Ahead Schedule in eMarket and ensure the Designated Entity is aware of its schedule. The ISO Forecast or Control Room Personnel will not make these initial notifications. • Dispatchable Resources committed in the Day-Ahead Market or subsequently committed for Real-Time operation will be notified of their schedule by ISO Control Room personnel following the 2200 completion of the ISO Reserve Adequacy and Regulation Market commitment. • Units requiring long lead-time notification will continue to be notified by the ISO Forecast Personnel.

  13. http://emkt.iso-ne.com/ Day-Ahead Market Results… Example: Startup Instructions 16:00 22:00 ISO DE

  14. Overview: Start-up Profile Starting and ramping units to fulfill obligations: • Based on unit parameter limitations below Economic Minimum the DE is responsible for submitting a start-up profile during the Re-Offer period (1600-1800) to meet the Day-Ahead Market cleared schedule. • Following the Re-Offer period, the Forecaster will enter a start-up profile provided by the DE’s for any units committed during the RAA process. As with any change in status, the station operator should contact the ISO operator prior to actually synchronizing to coordinate proper UCM selection and dispatch of the system.

  15. 06 05 12 04 03 07 18 08 16 22 Example: Start-up Profile Day-Ahead Re-Offer Reserve Adequacy Operating Day Start-up Sche-dule 6-Perform Analysis 7-Commit units 1-Create Schedule 2-Post Schedule to eMarket (Unit 1, 200, HE 0800) 5-Enter Startup profile Schedule (Unit 1) ISO 9-Enter Startup profile Schedule (Unit 2) 3-View DA Market Results 4-Call in Unit 1 Profile (e.g. 4 hr: 25, 75, 125, 175) 8-Provide Unit 2 Profile (e.g. 3 HR: 50, 100, 150) DE Unit 1 25 75 125 175 200 Unit 2 50 100 150 200

  16. Overview: Startup/Shutdown Instructions • Any unit may request to deviate from the ISO Current Operating Plan • Startup/ Shutdown requests require minimum 60 minute advance notice • Requests may be denied based on ISO reliability assessment

  17. ISO DE Approve/Deny Request Example: Startup/Shutdown Instructions Request Startup/Shutdown

  18. Overview: Fast Start Startup • Real-Time dispatch software produces fast start recommendation. • Operator accepts recommendation and sends DDP to unit with Fast Start signal. • Note: DDP may be in apparent conflict with Unit Operating Characteristics (e.g. Response Rate: 10 MW/Min, Economic Minimum: 280, DDP: 50). Unit should ramp to Economic Minimum.

  19. Example: Fast Start Startup Mode: Unit Summary Unit Msg Act Time ID Type UCM Gen DDP Dev Updated UN3 U 2 0 148 148 17:28:20 Emergency

  20. Overview: Fast Start Shutdown • Real-time dispatch software produces fast start shutdown recommendation. • Operator accepts shutdown recommendation and sends DDP with Shutdown Signal to RIG.

  21. Example: Fast Start Shutdown Mode: Unit Summary Unit Msg Act Time ID Type UCM Gen DDP Dev Updated UN3 D 4 148 0 148 18:23:20 Emergency

  22. Overview: Self-Schedule Changes • During an uneconomic change in self-schedule it is possible for the DE to continue to receive a DDP reflective of the current hour self-schedule or optimal DDP as determined by the Unit Dispatch System (UDS) that may conflict with ramping. • The unit must notify the Control Room when starting to ramp. • If at any time the economic dispatch of the unit would conflict with a Transmission Constraint or Emergency Generation condition, reliability and system security will take precedence. The System Operator would direct the DE to follow the communicated DDP regardless of self-schedule.

  23. Detail: Self-Schedule Changes (Increase) If an increase in the self-schedule is pending for the next hour: • For the purpose of transitioning to the new self-schedule, it is acceptable to operate the unit contrary to RIG dispatch instructions until the new self-schedule value is achieved. • The DE is responsible for ramping the unit based on the offer data Response Rate and requirement of centering the ramp across the top of the hour.

  24. 0655 0600 0700 0800 0705 Example: Self-Schedule Changes (Increase) 10 Minute Ramp (across top of hour) SS Change: 100 MW to 200MW Response Rate Offer: 10 MW/Min -Call Control Room to Begin Ramp DE 100 MW Ramp 200 Unit 1

  25. RIG Changes: Self-Schedule Changes (Increase) Current RIG Display Self Time DDP Sched Updated 150 100 06:55:00 ISO New England Electronic Dispatch REAL-TIME MARGINAL PRICES Unit Summary SMD RIG Display Self Time DDP Sched Updated 100 100 06:55:00

  26. Detail: Self-Schedule Changes (Decrease) Decrease in Self-schedule: • If a decrease of the self-schedule is pending for the next hour the DE should follow the communicated DDP as received via the RIG. • A DDP above the next hour self-schedule indicates that the unit is economic above its self-schedule.

  27. Overview: Response Rates • Dispatch software uses one response rate. • Response Rate offer value is the Manual Response Rate for the unit between Economic Maximum and Economic Minimum. • If a unit is participating in the regulation market, a Automatic Response Rate is determined by dividing the Regulation Capacity Offer (Mw) by 5 minutes. To indicate a change in the Automatic Response Rate the Regulation Capacity Offer must be modified.

  28. Example: Response Rates Automatic Response Rate (MW/Min) Regulation Offer MW 5 Minutes Example Unit actual Automatic Response Rate is 8 MW/Min. - Based on the 5 Minute performance the Unit Regulation Offer MW should be no greater than 40 MW. 8 MW/Min Automatic Response Rate 5 Minutes 40 Regulation Offer MW

  29. RIG Changes: Response Rates Current RIG Display Response Rates Manual Auto Up Down Up Down 10 10 5 5 ISO New England Electronic Dispatch REAL-TIME MARGINAL PRICES Unit Summary SMD RIG Display Resp Reg Rate Range 10 25

  30. Overview: Autocall • DE’s will be responsible for proper response to Autocall messages. • The following messages can be received by the Autocall program: • Startup and Shutdown for ICUs as a backup • Master/Satellite procedures (M/S 2, M/S 6) • NEPOOL Operating Procedures (NOP 4) • Custom messages (future)

  31. Overview: Limited Energy Generator (1) Limited Energy Generator • The SMD market permits any resource to offer into the Day-Ahead Market as a Limited Energy Generator (LEG) by submitting a Daily Maximum Energy total. • ISO Market Administrators will ensure that the Daily Maximum Energy value will not be exceeded in the Day-Ahead Energy Market unless additional energy is required to satisfy a Self-Schedule. • Note: if the Participant does not request during the Re-offer Period that the LEG Hourly Output schedule be honored the unit dispatch will be optimized for economics.

  32. Overview: Limited Energy Generator (2) Limited Energy Generator • The DE may redeclare the hourly LEG maximums (<= Eco Max, >= Eco Min) • LEG units must remain responsive to communicated DDP’s, changes in system conditions and other communicated instructions • If in response to a reportable event energy is prematurely depleted, the ISO will work with the Designated Entity to complete the LEG schedule

  33. RIG Changes Summary (1 of 2) Current RIG Display REAL-TIME MARGINAL PRICES Time: 17:30:53 Energy Price: 0.00 $/MWh TMSR Price: 0.00 $/MWh AGC Price: 0.00 $/Reg-hr TMNSR Price: 0.00 $/MWh TMOR Price: 0.00 $/MWh SMD RIG Display REAL-TIME MARGINAL PRICES Time: 17:30:53 Curr Hr Reg Market Price: 10.00 $/MWh Spin Res Market Price: ||||||||||| $/MWh Next Hr Reg Market Price: 11.00 $/MWh

  34. RIG Changes Summary (2 of 2) Current RIG Display Unit Summary Unit Msg Act Time Limits Self Response Rates Next Hr ID Type UCM Gen DDP Dev Updated HOL AHL ALL LOL Sched Manual Auto Energy up down up down Forecast UN1 N 4 134 130 4 17:28:20 200 180 120 100 100 10 10 4 4 134 SMD RIG Display Unit Summary Unit Msg Act Time Limits Self Resp Reg Dispatch ID Type UCM Gen DDP Dev Updated Eco Reg Reg Eco Emer Sched Rate Range Rate Max High Low Min Min $/MWh UN1 N 4 134 130 4 17:28:20 200 180 120 100 90 100 10 20 23.45

  35. Section Review • Definition of changes for Generators • Overview of suggested information supplied via RIGs

  36. Next Steps • CD ROM being produced by ISO-NE for Unit Operator training. • "Train-the-Trainer" sessions to be held beginning the second week of January. • 3 sessions to be held; in Central MA, Western MA/CT, and Coastal Region • Exact dates and locations to be announced.

  37. Questions?

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