“Simplified Electricity Market Models with Significant Intermittent Renewable Capacity: Evidence from Italy”
Christoph Graf (Stanford University), Federico Quaglia (Terna S.p.A.), and Frank Wolak (Stanford University)

Using hourly offer curves from the Italian day-ahead market and the real-time re-dispatch market for the period January 1, 2017 to December 31, 2018, we show how thermal generation unit owners profit from differences between a simplified day-ahead market design that ignores system security constraints as well as generation unit operating constraints, and real-time system operation where these constraints must be respected. We find that thermal generation unit owners increase or decrease their day-ahead offer prices depending on the probability that their final output will be increased or decreased relative to their day-ahead schedules because of real-time operating constraints. First, we estimate generation unit-level models of the probability of each of these outcomes conditional on forecast demand and renewable production in Italy and neighboring countries. Our most conservative estimate of the impact of a change in the probability a unit owner will have its day-ahead schedule increased in the real-time re-dispatch market implies a day-ahead offer price increase of 50 EUR/MWh if this probability increases from zero to one. If the probability of a day-ahead schedule decrease rises from zero to one the unit owner’s offer price is predicted to be 60 EUR/MWh less. Over our sample period, we find that the economic re-dispatch cost averaged approximately 15% of the total cost of energy valued at the day-ahead price.




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