Approximations made in day-ahead markets can result in suboptimal or even infeasible schedules for generating units and inaccurate predictions of actual costs and wind curtailment. Here we compare different optimal models of day-ahead markets based on unit commitment (UC) formulations, especially energy- vs. power-based UC; excluding or including startup and shutdown trajectories; and deterministic vs. “ideal” stochastic models to face wind uncertainty. The day-ahead hourly schedules are then evaluated against actual wind and load profiles using a (5-min) real-time dispatch model. We find that each simplification usually causes expected generation costs to increase by several percentage points, and results in significant understatement of expected wind curtailment and, in some cases, load interruptions
Original languageEnglish
Number of pages6
Publication statusPublished - 28 Jun 2017
EventErasmus Energy Forum 2017 - Rotterdam , Netherlands
Duration: 28 Jun 201729 Jun 2017


ConferenceErasmus Energy Forum 2017
Internet address

ID: 20366779