NOVEMBER 6, 2013 DRWG | HOLYOKE, MA

Doug SmithMANAGER OF DEMAND RESOURCE ADMINISTRATION

Review of requirements

DR Metering Configurations

Overview

• ISO has recently noticed several issues relating to metering configuration requirements

• Required data is not being submitted in some cases

• Conversations with some participants indicates a poitential lack of understanding of requirements and/or the reasons for them

• A review and discussion of allowable configurations may be helpful

• Material is sourced from the RA-DR training that was offered on Oct. 30

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Overview of the Configurations

• Facility Metered Load (FML) is the electricity used at a facility purchased from the grid

• Total Facility Load (TFL) is the total electricity used at a facility inclusive of that purchased from the grid and that produced by on-site Distributed Generation (DG)

• Only one asset at a facility can use either TFL or FML-based metering configurations – TFL and FML metering configurations cannot coexist at a facility

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TFL = FML + Distributed Generation

Types of Metering

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Meter Configuration Matrix

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For RTDR and RTEG Assets, real-time 5 minute interval data is required

(A) Load Reduction Only With No DG at the Facility

RTDR

• M1 required to submit 5-Minute telemetry through CFE/RTU

• Customer Baseline (CB) is calculated and based on M1 (FML)

• Average Hourly Load Reduction (HR) is CB-M1

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FacilityRTDR

Asset 123

M1

(B) DG Output Directly Metered

• RTDR, RTEG– M1 required to submit 5-Minute

telemetry through CFE/RTU. Average Hourly Output (HR) is M1

– If pushback is possible, M2 required to submit hourly data through SMS or 5-Minute data through CFE/RTU

• On-Peak, Seasonal Peak– M1 required to submit hourly data

through SMS, though M&V requirement is to have at least 15 minute interval data. HR is M1

– If pushback is possible, M2 required to submit hourly data through SMS

– No CB calculated

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Facility

M2

M1

DGAsset 456

(C) DG Only Used to Reduce Load at the Asset

• This metering configuration only applies to the RTEG DR Type where the EG is the only measure at the facility

• M1 required to submit 5-Minute telemetry through CFE/RTU

• CB is calculated and based on M1 (FML)

• HR is CB – M1

• From a data stream, CB and HR perspective, this metering configuration is like “Load Reduction Only with no DG at the facility” (A)

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Facility

M1

RTEGAsset 456

(D) Load Reduction Only With Directly Metered DG Used to Reduce Load at Another On-Site Asset

RTDR – Asset 123• M1 and M2 required to submit 5-

Minute telemetry through CFE/RTU. • CB is calculated and based on

M1 and M2 (TFL)• HR is CB – TFL

RTDR/RTEG/On-Peak/Seasonal Peak – Asset 789

• Uses the MC of “DG Output Directly Metered” (B) noted earlier

• For RTEG, MC of “DG only Used to Reduce Load at the Asset ” (C) at the Asset would not be allowed for this facility as there is another measure

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Facility

M1

M2

DGAsset 789

RTDRAsset 123

(E) DG Used to Reduce Load at the Asset and Directly Metered DG at Another On-Site Asset

RTEG Only• M1, M2 required to submit

5-Minute telemetry through RTU • CB is calculated and based on M1

and M2 (TFL)• HR is CB – TFL

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Facility

M1

M2

DGAsset 789

DGAsset 456

(F) Load Reduction Pursuant to M&V Plan

On-Peak, Seasonal Peak• Asset 789 submits demand reduction

values across performance hours in each month

• No CB is calculated

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FacilityPassive

Asset 789

Changes to Metering Configurations

• Once established, the metering configuration of a measure can only change with the addition of another measure at the same facility or when directly metering RTEG that was formerly DG used to reduce load

• Upon receipt of a second measure registration, ISO will coordinate the metering configuration change with the Lead Market Participant(s)

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Metering Configuration Considerations

• Beginning with full integration of RTDR with the energy market (planned for June 2017), TFL configuration goes away in all cases except when there is an RTDR and RTEG at the same facility– Only one RTDR type asset will exist behind a retail delivery point

• Metering and FML based performance at the Retail Delivery Point is required– This is required now for assets participating in Transitional Demand

Response

• Consideration should be given to utilizing Retail Delivery Point metering for any new assets being registered

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Availability Forecasting

• Control room operators need to know how much performance they should expect from these and other dispatchable resources in any given hour in order to reliably operate the system in real time.

• Requirement for DR is that hourly forecasted demand reduction be provided for the next two operating days– This is entered through the DRMUI– This should reflect the expected reduction if the resource is

dispatched to its full net CSO, and may be higher or lower than that CSO

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Winter Reliability Program for DR• Part of the overall Winter Reliability Solution (Appendix K)• For RTDR (no RTEG) asset with at least 100 KW reduction, capacity

must be in excess of any resource CSO• Runs from 12/1/2013 to 2/28/2014• Allows accepted assets to be dispatched by operator from 0500 to

2300 7 days a week• Commitment for initial 10 dispatches; additional performance

optional if dispatched• Dispatched by phone call from operator to DDE• Dispatch will be prior to or coincident with OP4 Action 2• Audit will be coincident with the seasonal audit of RTDR capacity

Resource the Assets are mapped to

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