2013 Load Impact Evaluation Capacity Bidding Program (CBP) Steve Braithwait, Dan Hansen, and Dave Armstrong Christensen Associates Energy Consulting DRMEC Spring Workshop May 7, 2014 May
2 Statewide CBP Programs Features of programs Methods and validation Ex-post load impacts (2013) Load impacts by program, product & event Ex-ante load impacts
May CBP Features Capacity ($/kW) payments for nominated load Energy ($/kWh) payments to bundled customers Monthly load reduction nominations (MW) Product-type options Day-ahead (DA) or Day-of (DO) notice Event windows (1-4; 2-6; or 4-8) 4 to 6 aggregators at each utility (a few are individual customers)
CBP Events May
5 Nominated Customer Accounts; by Utility, Year, and DA & DO Notice
Nominated Customers, by Industry Type May
7 Ex-Post Regression Model (Individual Customer Level) Dependent variable = kWh/hour Independent variables: To estimate hourly event-day load impacts -- – Indicator variables for each hour of every event day To control for weather conditions -- – CDH65_3MA and 24MA To establish typical hourly load profile -- – Separate hourly indicator variables for Monday, Tuesday - Thursday, and Friday To control for typical load level -- – Day-of-week indicator variables – Month-of-year indicator variables
May Ex-Post Regression Model (2) Independent variables (continued): Event-hour indicators for events of other DR programs in which the customer is enrolled Summer pricing season differences – Summer defined according to tariff season definitions – Separate summer load level and hourly load profile Day-of, morning-load adjustment to improve accuracy – Average hourly load from hour-ending 1 through 10
May Model Validation Estimate models with event-like non-event days withheld from the sample (one at a time) and examine performance of model predictions on those days (MAPE, MPE, R Sqr) Model variations included 18 different combinations of weather variables
May Model Validation (2) Also estimate “synthetic” event-day models Test significance of coefficients on variables for event-like non-event days Coefficients that are not statistically significant indicate that models do not falsely estimate load impacts on non-event days Examine sensitivity of estimated hourly load impacts on actual event days across 18 alternative specifications Compare predicted to actual loads on event-like days
May Model Validation (3) Findings from model validation: Synthetic event tests do not find significant “false” load impact estimates Little sensitivity of estimated load impacts across the tested specifications Models predict well on event-like days
May Sensitivity of Load Impact Estimates to Weather Variable Specification (PG&E)
May Actual and Predicted Loads – Average Event-Like Non-Event (SCE)
May CBP Ex-Post Load Impacts (2011 – 13) Typical Event – Average Event-Hour (MW)
May Ex-Ante Load Impact Simulation Process 1-in-2 and 1-in-10 Weather Conditions Simulate Hourly Reference Loads Estimate Customer-level Regression Coefficients Calculate % Load Impacts (Based on 3 Years of Ex- Post LI) Enrollment Forecasts Ex-Ante Load Impacts per Customer Aggregate Load Impacts
May Comparison of Previous Ex-Ante to Current Ex-Post and Ex-Ante [CBP]
Key Factors in Ex-Ante Changes PG&E believes that aggregators with both CBP and AMP contracts have focused on achieving AMP commitments, leading to lower CBP load impacts SCE anticipates movement of AMP-DA contract to CBP-DA, and shifting less responsive customer accounts from AMP-DO to CBP-DO SDG&E results varied somewhat due to unexpected changes in customer nominations, changes in performance of a few large customers, and changes in the mix of % load impacts in previous 3 years May
May Questions? Contact – Steve Braithwait or Dan Hansen, Christensen Associates Energy Consulting Madison, Wisconsin