Overview Of PJM Demand Response and Energy Efficiency. Issues September 22, Susan Covino, Senior Consultant Market Strategy

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1 Overview Of PJM Demand Response and Energy Efficiency MARAMA Workshop on Energy and Air Quality Issues September 22, 2008 Susan Covino, Senior Consultant Market Strategy

2 Energy price incentive changes in 2008 Energy Revenue incentive no longer available. Energy providers now paid the market price minus their cost (retail G&T) to buy the resold energy. Prior to 2008 energy demand response providers were not charged for the cost of their resold energy. Direct access to Energy market remains for demand responders. 2

3 Energy Market Economic Load Response* Self Scheduled Dispatched by PJM in Real Time Cleared by PJM in the Day Ahead Market Emergency Load Response Energy Only Option Full Emergency Load Response Synchronized Reserve * Incentive payment when LMP equals or exceeds $75/MWh expired 12/31/07 3

4 Yearly CSP Credit Economic annual total CSP revenue $50,000,000 $45,000,000 $40,000,000 $35,000,000 CSP Credit ($) $30,000,000 $25,000,000 $20,000,000 $15,000,000 $10,000, $5,000,000 $ Year 4

5 Economic annual total CSP curtailed Mwh Yearly Curtailed Load 700, , ,000 Cur rtailed Load (MWh h) 400, , , , Year 5

6 Demand Side Response Scheduled Curtailments August 8, ) rtailed Load (MW) Cu PJ JM LMP ($/MWh) Hour Ending 0 6 Economic Emergency PJM LMP

7 Capacity Market Reliability Pricing Model Load Management (LM)* Demand Resource (DR) Existing or Planned Bids into the forward RPM auctions Paid the auction clearing gprice Interruptible Load for Reliability (ILR) Certified to PJM 3 months before the delivery year Paid the final zonal ILR price *LM must respond to no more than 10 events of 6 hours duration between June 1 and September 30 of the delivery year or be subject to penalty 7

8 Demand Response Participation Volume in Capacity Market MW RPM Implemented Prior to RPM Implementation 2005/ / / / / /2012 Delivery Year ALM RPM - ILR RPM-DR 8

9 Synchronized Reserve Market Demand resource must: be capable of providing a response within 10 minutes have metering infrastructure in place to verify response and compliance (1 minute scan rate) Mandatory training for Curtailment Service Provider Subject to penalties for failure to perform during an event Limited to 25% of the synchronized reserve requirement in each Reserve Zone 9

10 CSP Credits vs. MWh Reductions Total Payments Cleared MWh $500,000 40,000 $450,000 $400,000 $350,000 $300,000 $250,000 $200,000 $150,000 $100,000 $50,000 35,000 30,000 25,000 20,000 15,000 10,000 5,000 Dollars MWh $0 0 Aug-06 Sep-06 Oct-06 Nov-06 Dec-06 Jan-07 Feb-07 Mar-07 Apr-07 May-07 Jun-07 Jul-07 Aug-07 Sep-07 Oct-07 Nov-07 Dec-07 Jan-08 10

11 Qualified Synchronized Reserves Participation: CSPs vs. Resources CSPs Registration IDs Qualified Synchronized Reserve Resources Aug-06 Sep-06 Oct-06 Nov-06 Dec-06 Jan-07 Feb-07 Mar-07 Apr-07 May-07 Jun-07 Jul-07 Aug-07 Sep-07 Oct-07 Nov-07 Dec-07 Jan-08 Feb-08 11

12 Regulation Market Must meet all of the requirements of regulation including real-time telemetry Mandatory training for Curtailment Service Provider Subject to penalty for failure to perform in response to PJM direction Limited it to 25% of the regulation requirement in the Reliability First Corporation Council region To date no demand resources have qualified for participation in the regulation market 12

13 Demand Response Roadmap Demand Response Roadmap Derived from many sources (DR opportunities identified at the Demand Response Symposium, MADRI, state commission DR working groups, PJM DSRWG, and the NARUC/FERC demand response collaborative Provides a guide for better coordination of demand response development and activity between the wholesale and retail markets Adopted unanimously by the Mid-Atlantic Demand Resources Initiative (MADRI) steering committee in late 2007 DR Symposium II held May 12 &13 focused on AMI/Data Management, Customer Education and Coordination of DR with Planning and the Reliability Pricing Model Five functional areas: dispatch, data management, settlement, planning process, forward price signals 13

14 Data Management Efficient communication of critical customer data without comprising customer privacy Lack of transparency and standardization for getting customer authorization Data Peak Load Contribution (PLC) value for ILR and DR PJM requirement to complete calculation by January 1 Option to put PLC value in the notes section of the customer s bill Loss Factor G+T (retail rate) Electric distribution company (EDC) account number 14

15 Data Management Action Items Develop standard customer data consent form for the region Maintain the AMI Pilot Matrix for the PJM region PJM to provide market participants with updates on the new Load Response application (targeted production date of 6/1/09) and development of Meter Data Service Provider certification and standards 15

16 Customer Education Action Items Speaker s Bureau established by the Mid- Atlantic Distributed Resources Initiative to develop general demand response messages and identify key policy makers and media outlets Improve customer s bills to show what they could have saved or did save by choosing DR Use text messages, cell phone messages, , etc. to more quickly and effectively make customers aware of high h load/high h cost days 16

17 Integration of Energy Efficiency into the Capacity Market Market design and rules before the Demand Response Steering Committee Measurement and Verification key to stakeholder support Goal to include Energy Efficiency in the upcoming Base Residual Auction to be conducted in May 2009 for the 2012/2013 Planning Year. 17

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