Find answers here to common questions about the Renewable Energy Self-Generation Bill Credit Transfer (RES-BCT) rate schedule.
This rate schedule allows local governments or campuses to generate energy from an eligible renewable generating facility for its own use (“generating account”) and to export energy not consumed by the generating account to our electrical grid. The exported energy is converted into bill credits that are applied to eligible “benefitting accounts” as designated by the local government or campus.
For the purposes of this rate plan, a “local government” is defined as a city, county, special district, school district, political subdivision, or other local public agency (e.g., water companies, sanitation districts) that does not sell electricity exported to the grid to a 3rd party. A local government does not include the state, any agency or department of the state, or joint powers authority, other than a campus. A “campus” is defined as an individual community college campus, individual California State University Campus, or individual University of California campus.
Any energy exported by your renewable generating facility to the grid is calculated into bill credits and applied monthly to the designated benefiting account(s). Credits are determined based on the Time-of-Use (TOU) Utility Generation (UG) energy rate components applicable under the generating account’s otherwise applicable tariff (OAT).
Both the generating account and benefitting account(s) are billed monthly for all metered usage at their OAT rates; however, the “generation component” of the benefitting account(s) will be reduced by any generation bill credits.
You must designate what percentage of the generation credit is applied to each benefitting account, using Form 14-789.
Not more than once per year, you can submit an updated Benefitting Account Designation Form to change benefitting account(s) or revise the percentage allocation. The form must be submitted 60 days prior to the change and all changes will remain in effect for a minimum of 12 months. After 12 months, changes can again be submitted via Form 14-789.
No, this is a limited rate plan available to customers on a first-come, first-served basis. We are currently accepting new applications to participate in this rate plan.
Yes, the following fees apply to this rate plan:
- $500.00 one-time set-up fee per generating account
- $30.00 monthly billing fee per generating account
The generating account’s billing meter will suffice, provided it is a Time-of-Use meter capable of recording the flow of electricity in two directions and allows us to bill the generating account according to its otherwise applicable tariff (OAT). Benefitting accounts must have separate Time-of-Use meters.
You are responsible for all costs associated with metering requirements for electricity exported to the grid, including any cost for metering associated with multiple generators interconnected with the generating account.
Yes, the retail account interconnected to the generating facility (“generating account”) is subject to standby charges. Benefitting accounts are not subject to standby charges.
Yes, departing load charges do apply to the retail account interconnected to the generating facility (“generating account”).
You are responsible for any upgrades, and must pay for all costs associated with meeting interconnection requirements under Tariff Rule 21. These costs are not reimbursed.
No, electricity exported by the Local Government or Campus may not be sold to a third party.
Generators must be sized to offset either a portion or all of—but not exceed—the load from the generating account and designated benefitting accounts. The maximum acceptable generating capacity per generating account is 5 MW.
We compare the prior 12-months historical usage in kilowatt hours (kWh) to the estimated production of the generating facility. If the estimated generation exceeds the historical (and anticipated) load of the generating and benefitting accounts, the generating facility is considered oversized. If you don’t have 12 months of historical usage and/or plan to increase load, we may require documentation to substantiate the anticipated load.
An account can change to a Time-of-Use (TOU) rate to qualify as a generating or benefitting account, provided there is a Time-of-Use rate for which the account qualifies, and the account hasn’t had a change in rate schedule within the previous 12 months. You must change to a Time-of-Use rate at least 60 days prior to the date when billing will begin under this rate schedule.
No, generating and benefitting accounts participating in NEM are not eligible for service under this rate plan.
Yes, customers served under this rate plan are eligible for California Solar Initiative and Self-Generation Incentive Program incentives.
No, this rate is available to bundled service customers only. Customers participating in Community Choice Aggregation or Direct Access are not bundled service Customers.
State wide, there is a program limit of 250 MW. We will offer this rate plan on a first-come, first-served basis until the combined rated generating capacity of all generators participating reaches 124.591 MW, which is our allocated share of the 250 MW; or until the combined state-wide cumulative rated generating capacity of all participating generators within the service territories of PG&E, SDG&E and SCE reaches 250 MW.
You will retain ownership of any renewable energy credits associated with energy you export to the grid.
Generators installed on greenfields or virgin sites can be served under RES-BCT under the following conditions:
- Must not serve load (other than minimal auxiliary load)
- Be served under the TOU-GS-1 Option B, C or TOU-GS-1-RTP.
- Adhere to Rule 2.h Added Facilities
- Typically SCE does not allow a new Service Delivery Point if there is no load (Rule 15) and or allow more than one meter/Service Delivery Point for a single Premises (Rule 16)
- Departing load (DL) charges apply to all generators (new and existing customers). However, because generators installed on Greenfields are not allowed to serve load, the DL will calculate to zero.”