  Energy storage is a key enabler towards a low-emission electricity system,
but requires appropriate dispatch models to be economically coordinated with
other generation resources in bulk power systems. This paper analyzes how
different dispatch models and bidding strategies would affect the utilization
of storage with various durations in deregulated power systems. We use a
dynamic programming model to calculate the operation opportunity value of
storage from price predictions, and use the opportunity value result as a base
for designing market bids. We compare two market bidding and dispatch models in
single-period economic dispatch: one without state of charge (SoC) constraints
and one with SoC constraints. We test the two storage dispatch models, combined
with different price predictions and storage durations, using historical
real-time price data from New York Independent System Operator. We compare the
utilization rate with respect to results from perfect price forecast cases. Our
result shows that while price prediction accuracy is critical for short
duration storage with a less than four hours capacity, storage with a duration
longer than twelve hours can easily achieve a utilization rate higher than 80\%
even with naive day-ahead price predictions. Modeling storage bids as dependent
of SoC in single-period real-time dispatch will provide around 5% of
improvement in storage utilization over all duration cases and bidding
strategies, and higher renewable share will likely improve storage utilization
rate due to higher occurrence of negative prices.
