7416

• UCREFRP Catalog Number: 7416
• Author: U.S. Fish and Wildlife Service.
• Title: Flaming Gorge Aspinall Joint Operations Study December, 15, 1988-Draft.
• USFW Year: 1988.
• USFW - Doc Type: Denver, Colorado.
• Copyright Material: NO

The range of daily release is closely tied to the average daily
release volume, which is, in turn, related to the monthly release
volume specified the Bureau. During low runoff years, such as
1987 and 1988, low monthly volumes resulted in substantial periods
of minimum releases while maximum releases were constrained.
During high runoff, years such as 1984 and 1986, extremely high
monthly volumes dictated that the powerplant be operated at
maximum capacity continuously with little or no daily fluctuation.
Economic Effects of Altered Operation Schedules at Flaming Gorge
and the Aspinall Unit J
The assumed flow requirements (constrained releases from Flaming
Gorge) would result in rescheduled water releases, which in turn
would result in rescheduled electrical generation at Flaming
Gorge and the Aspinall Unit. Although the total amount of energy
(kwh) generated at each facility would be the same, Western's
revenues would be affected because of the different monthly rates
charged for nonfirm or surplus electrical power.
E. FLAMING GORGE OPERATIONAL CONSIDERATIONS
The constrained releases at Flaming Gorge are assumed to
reschedule 95,000 acre-feet of water normally released in August
and September to October and December. The Bureau normally
attempts to release water so that the Project reservoirs are low
in January in order to accommodate the high runoff of the
following spring. Ignoring any variation in reservoir head for
simplicity, this amount of water generates 35,081 MWH of energy
at Flaming Gorge. Due to seasonal differences in electrical
power rates, rescheduling this generation represents a revenue
loss to Western. This analysis assumes that this small amount of
energy would be sold as Fuel Replacement Energy, a product whose
rate differs on a monthly basis. The calculation for the short-
term annual revenue loss to Western is shown below:
35,081 MWh x $0.025/kwh (summer rate) = $877,025
35,081 MWh x $0.01733/kwh (fall rate) = $607.954
Difference $269,071
J This discussion was excerpted from a draft prepared by
Clayton Palmer of Western for the Recovery Implementation
Plan Environmental Assessment. The draft has been edited
for clarity and is provided only as an illustration of how
Western might analyze changes in a reservoirs operations.
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