B O N N E V I L L E P O W E R A D M I N I S T R A T I O N
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Refer to the Transmission Plan for detailed information regarding required products and services, as well as, market
factors that may affect delivery of service.
The current long range sales forecast is based on sales and revenues from the BP-22 Transmission Rate Case, with the
out-years adjusted for identified factors, particularly Network load and Network contract demand. Network transmission
service includes products used to either serve load to customers, or move transmission from a Point-of-Receipt to Point-
of-Delivery for load service and marketing usage. Network Integration (NT) sales serve load to customers and are based
on metered customer loads at the peak hour of the Transmission load in the month. The load forecast is based on
forecast developed by Agency Load Forecast, with an annual load growth applied to out-years. Point-to-Point service
(PTP) moves energy over transmission paths in the Network based on reserved demand (firm and non-firm). Long-term
service includes service for one year or more with the demand amount specified to move transmission from Point-Of-
Receipt (POR) to Point of Delivery (POD) over specified time duration. Short-term service includes service less than one
year and is market driven by hydro and pricing conditions.
Intertie sales (IS) likewise are based on demand and capacity. Long-term sales for IS include sales durations of one year
or longer and are based on confirmed reserved capacities and deferrals. The long-term capacity on the Southern Intertie
is almost fully subscribed from north-to-south with high rates of renewals (95%), so added sales are limited. Short-term
IS sales include demand for near-term service with regional price spreads as the primary inputs for customer behavior.
Another sales category includes required Ancillary Services. As described in Section 3 of the OATT, customers that
purchase Network and Intertie transmission are required to acquire Scheduling, Control, and Dispatch service
(SCD). Other Ancillary Services include products that apply to certain customers only.
Additionally, BPA has recognized an increasingly dynamic, uncertain and changing environment. We've seen changes in
traditional operational, marketing and planning practices including oversupply of energy, negative market prices, a
movement towards smart-grids, and an evolving regulatory environment responding to retail customer self-supply and
distributed energy. Across the Northwest, states are committing to carbon-free power. Washington, Oregon, Idaho and
California have pledged and adopted legislation to move to clean energy. To meet landmark clean energy goals, coal
plants will need to be retired and our Transmission system will need to adapt in order to supply clean, reliable, and
controllable resources that can meet energy demands across all hours. Energy storage projects could be on the horizon
and may require system reinforcement when built. BPA and the region are increasingly looking to non-wire (commercial
and technical alternatives) to meet dynamic system demands and therefore very large infrastructure builds might
become less likely in the next decade, while system adaptations may be required in new ways not yet determined. Due
to declining costs of renewable energy, Transmission needs to prepare to respond to potential variable energy
resources. Our Transmission assets may also need the ability to realize the value of sub-hourly dispatch with flexible and
low carbon hydro resources. Transmission is also seeing changes in use and system operations. With the emergence and
growth of the energy imbalance markets, the region needs a well-designed electricity market built on a foundation of
resource adequacy, intra-hour energy balancing, and the ability to compensate explicitly for capacity resources that
provide system reliability and flexibility. Our Transmission assets and systems will need to be modernized to
accommodate these shifts in the industry and in demand.