108
Electric – Retail – Baltimore Gas and Electric Company
28. Small Generator Interconnection Standards
Availability: For all residential and non-residential customers within the Company’s service
territory seeking to interconnect energy generation resources to the electric distribution system.
In accordance with COMAR 20.50.09: Small Generator Interconnection Standards, the
Company has established protocols for the communication, metering, and interconnection with
customers who are seeking to install a generation resource. This protocol will ensure the proper
engineering and compliance with local, regional, and national codes.
Cost: The Customer will be charged in accordance with interconnection levels as determined by
COMAR 20.50.09. The following application fees apply:
Level 1 - No charge;
Level 2 - $50 plus $1 per kW of rated generating facility output;
Level 3 - $100 plus $2 per kW of rated generating facility output; and
Level 4 - $100 plus $2 per kW of rated generating facility output.
Approval: After receiving a standard small generator interconnection agreement from the
Company, the Customer will have the generation equipment installed and inspected by the local
municipality. Upon receiving a certification of inspection from the municipality, the Customer
will submit a certificate of completion to the Company. The company will then install the
necessary meter equipment on the premises.
The Company shall maintain a database to track the installation of new generation
resources within the service territory and will submit reports to the Commission in accordance
with COMAR 20.50.09.
29. Reserved for Future Use
P.S.C. Md. – E-6 (Suppl.564)
Filed 04/29/15 – Effective 06/01/15
Baltimore Gas and Electric Company – Electric – Retail
109
30. Demand Resource Surcharge
Distribution Customers receiving service under Schedules R, RL, G, GU, GS,
GL P, or T are subject to a Demand Resource Surcharge. This Surcharge recovers the
Contract for Difference payments and associated incremental costs incurred through the
issuance of Requests for Proposals (Gap RFPs) as provided in Maryland Public Service
Commission Order No. 82511 in Case No. 9149, issued March 11, 2009. The Gap RFP
secures a demand response resource commitment for the June 1, 2011 through May
31, 2016 power planning years with a two-year extension provision (June 1, 2016 –
May 31, 2018).
Contracts awarded through the Gap RFP are structured as a Contract for
Differences, where the contract price of the demand response resource is compared
against the PJM Reliability Pricing Model clearing price and actual delivered capacity
for each power planning year. This difference, along with any approved incremental
costs, determines the total annual Surcharge amount. Once the annual Surcharge
amount is determined, it is allocated proportionately based on each Schedule’s Peak
Load Contribution to the total peak load. A rate per kilowatt-hour is then derived based
on each Schedule’s forecasted sales for the planning year. Any imbalance between
the actual costs and Surcharge amount shall be reconciled annually over the
subsequent planning year. A final, one-time reconciliation shall be conducted upon
termination of all Gap RFP contracts.
The current Demand Resource Surcharges are available on the BGE website at
www.bge.com.
31. Electric Reliability Investment Initiative Charge
The Electric Reliability Investment (“ERI”) initiative Charge recovers certain
expenditures approved during Case No. 9326, Order No. 86060 or during future compliance
filings.
Calculation of Charge
The ERI initiative Charge is calculated annually and is determined for each rate schedule
by first allocating the revenue requirement (based on Eligible Costs as defined below) based on
the NCP hourly peak loads (34 kV level) for each Schedule approved during Case No. 9326 in
Order No. 86060 or any subsequent base rate case during the existence of Rider 31. The resulting
amounts, plus any true-up amounts as determined below, are then divided by the estimated per
kilowatt-hour billing determinants for each applicable Schedule. Details concerning the
calculation of the ERI initiative Charge are filed with and approved by the Commission prior to
their use in billing. The ERI initiative Charge shall be separately stated on the Customer’s
monthly electric bill.
(Continued On Next Page)
P.S.C. Md. – E-6 (Suppl. 544)
Filed 04/21/14 – Effective 06/01/14
110
Electric – Retail – Baltimore Gas and Electric Company
Rider 31 continued
Rate
Schedule Rate
R
RL
G/GU
GS
GL
P
$0.00018
$0.00014
$0.00016
$0.00006
$0.00014
$0.00014
per kWh
per kWh
per kWh
per kWh
per kWh
per kWh
Eligible Costs
The revenue requirement for the ERI initiative Charge is based on eligible costs incurred
by the Company associated solely with ERI initiative projects filed and approved by the
Commission each year. They include the following categories:
a) Depreciation and amortization,
b) Operation and maintenance costs,
c) Earnings on the net investment as determined by applying the Company’s most recent
Electric authorized rate of return, adjusted for taxes, to the average investment balance net
of deferred taxes, and
d) Applicable taxes.
True-up
An annual true-up will be conducted to include:
a) For each rate schedule, the Imbalance is the difference between cumulative costs eligible
for recovery and revenues collected through the ERI initiative Charge each year. The
estimated Imbalance includes the actual data available and 3 months of estimated data.
An Imbalance is debited or credited against the costs eligible for recovery each year.
During its disposition, an Imbalance accrues a return at the Company’s most recent
authorized electric system rate of return. Such rate is adjusted for taxes, when the
Imbalance represents an under-collection of costs to the Company.
P.S.C. Md. – E-6 (Suppl.569)
Filed 11/02/2015 – Effective 01/01/2016