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Demand Resources Working Group July 1, 2009

Metering Configurations for Real-Time Demand Response and Real-Time Emergency Generation Resources in the Forward Capacity Market. Demand Resources Working Group July 1, 2009. M-MVDR Conforming Changes.

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Demand Resources Working Group July 1, 2009

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  1. Metering Configurations for Real-Time Demand Response and Real-Time Emergency Generation Resources in the Forward Capacity Market Demand Resources Working Group July 1, 2009

  2. M-MVDR Conforming Changes • The approved Market Rule changes for Demand Resources will require conforming changes to M-MVDR. • This presentation is the second presentation on the set of metering configuration for FCM. • The proposed changes are designed to ensure the appropriate calculations of load reductions from RTEG and RTDR Assets with and without the presence of Distributed Generation.

  3. RTDR and RTEG Metering Configurations • The ISO proposes to replace the Metering Configurations described in Section A4.3.1 for RTDR and RTEG Assets with the following: • Type 1: RTEG / DG Directly Metered • Type 2: RTEG Only Using Bill Meter • Type 3: Load Reduction Only (No DG at the Asset) • Type 4: DG Used to Reduce Load at the Asset • Type 5: Load Reduction with DG used at a different Asset • Each Metering Configuration is described in the following slides.

  4. Measurement and VerificationDocumentation of Demand Reduction Values III.13.1.4.3.1.3. Distributed Generation, Real-Time Demand Response, and Real-Time Emergency Generation Resource projects must include individual metering or a metering protocol consistent with the measurement and verification requirements

  5. Capacity Values of Certain Distributed Generation III.13.7.1.5.2. If across Demand Resource On-Peak Hours, Demand Resource Seasonal Peak Hours, Demand Resource Critical Peak Hours, Real-Time Demand Response Event Hours, or Real-Time Emergency Generation Event Hours, as appropriate, a Distributed Generation resource’s monthly average hourly output is greater than the monthly average hourly load of the end-use customer to which the resource is directly connected, the Capacity Value of the portion of output exceeding the customer’s load for the month will be the Demand Reduction Value for that portion of the output.

  6. Market Rule Section III.13.7.1.5.2 (Example) • RTEG Asset with the ability to “push back” power onto the electricity grid.

  7. Demand Reduction Values (DRV) III.13.7.1.5.3. DRV is the quantity of reduced demand, calculated at the end-use customer meter, produced by a Demand Resource. All DRVs are based on reductions in end-use demand on the electricity network in the New England Control Area…

  8. DRV (continued) III.13.7.1.5.3. …The DRV of a combined Demand Resource that reduces load and generates output simultaneously for a single facility shall be its Average Hourly Output, if registered as an On-Peak Demand Resource, a Seasonal Peak Demand Resource, or a RTEG Resource, or Weighted Average Hourly Output, if registered as … a RTDR Resource, which reflects the combined impact of the load reduction and Distributed Generation output on reducing overall end-use demand on the electricity network in the New England Control Area.

  9. Terms used in this Presentation • Facility • An end-use metered customer’s building or home. • RTDR / RTEG Asset • One or more Facilities located at a single Node, reporting data as a single set of values and assigned a unique Asset ID by the ISO • DG Output (DG) • The metered output of a Distributed Generator • Customer Baseline (CB) • An estimate of a Asset’s electricity consumption had it not responded to a RTDR or RTEG event. • Facility Metered Load (FML) • Electricity consumed at a Facility that is purchased from the Grid. • Total Facility Load (TFL) • Total Facility Load is the total electricity consumed at a Facility inclusive of that purchased from the Grid and that produced on-site from a Distributed Generator. TFL = FML + DG • Hourly Reduction (HR) • The reduction in the Asset’s electricity consumption resulting from responding to a RTDR or RTEG event.

  10. Metering Configuration - Summary

  11. Issues Being Addressed • Satisfy MR 1 requirements • Have RTDR mixed with RTEG at same facility • Must be separated for FCM • Behind the meter generation directly effects FML • CB significantly affected by behind the meter generation Grid DG Facility Total Facility Load = 6 MW M M DG Output = 0 MW 1 MW 3 MW 6 MW Facility Metered Load = 6 MW 5 MW 3 MW 0 MW

  12. Metering Configurations

  13. Type 1: DG Only(DG directly metered)

  14. Type 1: DG Directly Metered • Example: • Customer operates an emergency generator during OP4 Action 12 events. • DG unit is registered as part of an RTEG Resource. • CB: None • HR = DG Output • FML used to enforce MR1 Section III.13.7.1.5.2 Facility Metered Load = 5 MW DG Output = 1 MW Grid DG Facility Total Facility Load = 6 MW M M

  15. Type 2: RTEG Only(No RTDR, no other Asset)

  16. Type 2: RTEG Metered Billing Meter • Example: • Customer operates an emergency generator during OP4 Action 12 events. • DG unit is registered as part of an RTEG Resource. • CB based on FML • HR = CB - FML • FML used to enforce MR1 Section III.13.7.1.5.2 Facility Metered Load = 5 MW DG Output = 1 MW Grid DG Facility Total Facility Load = 6 MW M M

  17. Type 3: RTDR Only (No DG)

  18. Type 3: Load Reduction Only (No DG) • Example: • Customer reduces lighting load during RTDR events. • Asset is registered as part of a RTDR Resource. • CB based on FML • HR = CB - FML Facility Metered Load = 5 MW Grid Facility Total Facility Load = 5 MW M

  19. Type 4: DG Used to Reduce Load

  20. Type 4: DG Used to Reduce Load • Example: • Customer increases the output of their Combined Heat & Power DG unit during RTDR events. • CB based on FML • HR = CB - FML • FML to calculate CB and used to enforce MR1 Section III.13.7.1.5.2 Facility Metered Load = 5 MW DG Output = 1 MW Grid DG Facility Total Facility Load = 6 MW M M

  21. Type 5: Load Reduction with DG used at a different Asset

  22. Type 5: Load Reduction with DG used at a different Asset • Example: • Customer reduces lighting loads during RTDR events. • The customer’s emergency generator is registered as part of a different RTEG Asset. • CB based on TFL • HR = CB – TFL Facility Metered Load = 5 MW DG Output = 1 MW Grid DG Facility Total Facility Load = 6 MW M M

  23. General Conditions for All Metering Configurations • Assets can use only one Metering Configuration. • All Facilities associated with an Asset must use the same Metering Configuration. • Assets with different Metering Configurations can be associated with a single Demand Resource of the same Demand Resource Type.

  24. Appendix: Market Rule and M-MVDR References

  25. Market Rule Definitions • For purposes of the Forward Capacity Market, “Distributed Generation” shall mean generation resources directly connected to end-use customer load and located behind the end-use customer’s billing meter, which reduce the amount of energy that would otherwise have been produced by other capacity resources on the electricity network in the New England Control Area during Demand Resource On-Peak Hours, Demand Resource Seasonal Peak Hours, Demand Resource Critical Peak Hours, Real-Time Demand Response Event Hours, or Real-Time Emergency Generation Event Hours, provided that the aggregate nameplate capacity of the generation resource does not exceed 5 MW, or does not exceed the most recent annual non-coincident peak demand of the end-use metered customer at the location where the generation resource is directly connected, whichever is greater. Distributed Generation resources are not eligible for energy payments from ISO-administered energy markets. Generation resources cannot participate in the Forward Capacity Market as Demand Resources, unless they meet the definition of Distributed Generation.

  26. Market Rule Definitions (Continued) • “Real-Time Emergency Generation Resource” is Distributed Generation whose Federal, State and/or local air quality permit(s) limit the operation of these generators in response to requests from the ISO to the times when the ISO implements voltage reductions of five percent of normal operating voltage that require more than 10 minutes to implement. Real-Time Emergency Generation Resources must be: (i) capable of curtailing their electric consumption from the New England grid within 30 minutes of receiving a Dispatch Instruction from the ISO; and (ii) continue that curtailment until receiving a Dispatch Instruction to restore their consumption

  27. M-MVDR Appendix A: • Section A2.7 (6) and (7) requires Distributed Generation to provide facility load data consistent with Sections 9.2 (6a) and (6b) • (6)The Project Sponsor must report to the ISO the most recent annual non-coincident peak demand (absent Distributed Generation output) of the end-use metered customer at the location where the Distributed Generation resource is directly connected for each year that the Distributed Generation resource participates in the Forward Capacity Market. • (7) For each month of the Capacity Commitment Period, the Project Sponsor must report the monthly average hourly load of the end-use customer to which the Distributed Generation resource is directly connected separately from the Distributed Generation resource’s monthly average hourly output. • Section A4.1 establishes the requirement that the term Interval Meter used in Appendix A will mean a meter that records in 5-minute intervals. • The term Interval Meter as used throughout this Appendix A refers to a meter that records energy consumption (or generation) on at least a five minute basis and may store energy consumption (or generation) to a finer granularity.

  28. M-MVDR • Sections 9.2 (6a) and (6b) requires a Participant to measure and report on the load at the facility where Distributed Generation is installed • (a) Report to the ISO the most recent annual non-coincident peak demand (absent Distributed Generation output) of the end-use metered customer at the location where the Distributed Generation resource is directly connected for each year that the Distributed Generation resource participates in the Forward Capacity Market; and • (b) Report the monthly average hourly load of the end-use customer to which the Distributed Generation resource is directly connected separately from the Distributed Generation resource’s monthly average hourly output for each month of the Capacity Commitment Period. • The annual non-coincident peak demand data is used for qualification to ensure the resource complies with the definition of Distributed Generation. The monthly average hourly load data is used in monthly settlement as described in Section III.13.7.5.2

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