WSP02437

• File Number: 8220.100.50
• Description: CRSP - Power Issues
• Basin: Colorado Mainstem
• Date: 1/1/1982
• Author: West. Sys. Coord. Co
• Title: Western Systems Coordinating Council Ten-Year Coordinated Plan Summary 1982 - 1991
• Water Supply Pro - Doc Type: Publication

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63

STATE OF THE WSCC
INTERCONNECTED BULK POWER SYSTEM
THROUGH 1991

SUMMARY

1981 SYSTEM OPERATION

. The WSCC non-coincidental peak demand (83,966 MW) occurred in August
representing a 3.5% increase over the 1980 peak demand. The WSCC
total energy load was 506,807 GWh, 4.5% above the 1980 total energy
load.

. Summer operating reserve levels fell below minimum acceptable levels
in Northern California due to unusually hot weather and a high
incidence of generating unit forced outages.

. Columbia River January-July runoff was 103.5 million acre feet or
94% of the 15 year average.

. The amount of Northwest energy transfer over the 500 kV AC and 800
kV DC Pacific Interties to California set a record exceeding the
previous record year (1976) by 6.6%. The Northwest to California
net energy transfer, which includes a significant amount from
Canadian sources, was 27,440 GWH.

. The transmission system within the Rocky Mountain Power Area was
stressed on occasion beyond single contingency limits due to
transmission limitations.

. Loop flow continued to adversely impact the transfer of additional
non-oil-fired energy to displace oil-fired energy in California.
The major loop flow mean was 208 MW clockwise, and the loop flow
extremes were 896 MW clockwise and 828 MW counterclDckwise.
Requests for schedule curtailments to control loop flow were in
effect 1507 hours for clockwise loop flow and 1304 hours for
counterclockwise loop flow resulting in a total of 2811 curtailment
hours or 32 percent of the year.

. Principal new generating resources placed in service
1,445 MW Coal, 250 MW Hydro,
405 MW Combustion Turbine and 100 MW Pumped
Storage.

. Major transmission additions were placed in service in the Northwest
Power Pool Area (Midpoint-Malin 500 kV), Rocky Mountain Power Area
(Laramie River Station 345 kV lines) and California-Nevada Power
Area (Valmy-Tracy 345 kV).

. Twelve reportable disturbances occurred and in all cases were
quickly isolated, thereby minimizing the regional impact and
enabling timely restoration. The most noteworthy disturbance was