| (-a-) BDRC-CLASS -- Rate
class billing determinants used to establish distribution base rates
in the most recently completed base-rate proceeding. Energy-based
billing determinants will be used for those rate classes that do not
include any demand charges, and demand-based billing determinants
will be used for those rate classes that include demand charges.
(-b-) RORRC -- After-tax
rate of return approved by the commission in the electric utility's
most recently completed base-rate proceeding.
(-c-) ALLOCRC-CLASS --
Rate class allocation factor value determined under the provisions
of subparagraph (C) of this paragraph.
(-d-) DCRFLGA -- The value of &Sgr;(DISTREVRC-CLASS * %GROWTHCLASS )
in the most recent distribution cost recovery factor proceeding for
the utility since its most recently completed base-rate proceeding,
or zero if there are no distribution cost recovery factor proceedings
since the utility's most recently completed base-rate proceeding.
(C) Class allocation factors. For calculating RCRR
rates, the baseline rate-class allocation factors used to allocate
distribution invested capital in the most recently completed base-rate
proceeding will be used.
(D) Customer classification. For the purposes of establishing
RCRR rates, customers will be classified according to the rate classes
established in the electric utility's most recently completed base-rate
proceeding.
(2) Distribution Cost Recovery Factor. This paragraph
provides a mechanism for an electric utility to request to recover
certain resiliency-related costs deferred as a regulatory asset as
part of a distribution cost recovery factor proceeding under §25.243
of this title (relating to Distribution Cost Recovery Factor (DCRF)),
consistent with PURA §38.078(k).
(A) Notwithstanding the existing requirements of §25.243
of this title, a utility eligible to request a distribution cost recovery
factor under §25.243 of this title must, as part of an application
under §25.243 of this title, request to include any resiliency-related
costs deferred as a regulatory asset under this subsection in its
DCRF rates.
(B) DCRF rates established consistent with this paragraph
must be calculated in a manner identical to the DCRF rates described
in §25.234 of this title, with the exception that the DCRF rate
for each rate class must be calculated using the following formula:
((DICC - DICRC )
* RORAT ) + (DEPRC -
DEPRRC ) + (FITC -
FITRC ) + (OTC -
OTRC ) + RAMORT - &Sgr; (DISTREVRC-CLASS * %GROWTHCLASS )]
* ALLOCCLASS / BDC-CLASS
Where the value of RAMORT must be equal to a reasonable annual
amortization amount of the resiliency-related regulatory asset.
(C) Upon the establishment of an DCRF rate under this
paragraph, the resiliency-related regulatory asset balance will be
reduced at an annual rate by the value of RAMORT.
(3) Reconciliation.
(A) Resiliency-related amounts recovered through rates
approved under this subsection are subject to reconciliation in the
first base-rate proceeding for the electric utility that is filed
after the effective date of the rates. As part of the reconciliation,
the commission will determine if the resiliency-related costs are
reasonable, necessary, and prudent.
(B) Any amounts recovered through rates approved under
this subsection that are found to have been unreasonable, unnecessary,
or imprudent, plus the corresponding return and taxes, must be refunded
with carrying costs. In any proceeding in which the commission determines
that a utility has included in rates any amounts deemed unreasonable,
unnecessary, or imprudent, the commission may order a compliance proceeding
to determine the amounts and manner of any necessary refunds to ratepayers,
including carrying costs. Carrying costs will be determined as follows:
(i) For the time period beginning with the date on
which over-recovery is determined to have begun to the effective date
of the electric utility's base rates set in the base-rate proceeding
in which the costs are reconciled, carrying costs will accrue monthly
and will be calculated using an effective monthly interest rate based
on the same rate of return that was applied to the resiliency costs
included in rates.
(ii) For the time period beginning with the effective
date of the electric utility's rates set in the base-rate proceeding
in which the costs are reconciled, carrying costs will accrue monthly
and will be calculated using an effective monthly interest rate based
on the electric utility's rate of return authorized in that base-rate
proceeding.
(D) In any base-rate proceeding in which resiliency-related
costs are being reconciled, the electric utility must separately include
as part of its base-rate application testimony, schedules and workpapers
sufficient to enable a comprehensive review of all resiliency-related
costs included in each and every rider under this subsection that
have not yet been reconciled. Such information must include, but is
not limited to, the dates when the individual resiliency-related projects
began providing service to the public, as well as the costs associated
with the individual resiliency-related projects.
(g) Reporting requirements. An electric utility with
a commission-approved resiliency plan must file an annual resiliency
plan report by May 1 of each year, beginning the year after the plan
is approved. The annual resiliency plan report must include the following
information:
(1) until the resiliency plan is fully implemented,
an implementation status update consisting of:
(A) a list of each resiliency plan measure completed
in the prior calendar year, and the actual capital costs and operations
and maintenance expenses incurred in the prior year attributable to
each measure;
(B) a list of each resiliency plan measure scheduled
for completion in the upcoming year, and an estimate of capital costs
and operations and maintenance expenses for each resiliency plan measure
scheduled for completion in the upcoming calendar year; and
(C) an explanation for any material changes in the
implementation timeline or costs associated with implementing the
resiliency plan; and
(2) until the third anniversary of the plan being fully
implemented, a resiliency benefit update consisting of:
(A) a report on the occurrence of any resiliency events
the resiliency plan or a previously-implemented resiliency plan was
intended to address, including a comparison of the frequency and magnitude
of these events with any projections contained in the resiliency plan
or a resiliency plan previously-implemented by the electric utility;
(B) an evaluation of the effectiveness of each implemented
resiliency plan measure in preventing, withstanding, mitigating, or
more promptly recovering from the risks posed by any resiliency events
that measure was implemented to address. This evaluation must include
an analysis using the metric or criteria contained in the resiliency
plan for that measure, and a comparison of the measure's actual effectiveness
with its projected effectiveness.
(C) an update on the expected impact of implemented
resiliency plan measures, as appropriate for each measure, on system
restoration costs, reduction in the frequency or duration of outages
for customers at the location for which a resiliency plan was implemented,
and any improvement in the overall service reliability for customers.
(3) When submitting an updated resiliency plan, the
utility must include in the evidence supporting the plan, any information
from prior resiliency benefit updates related to previously-approved
measures designed to address the same or similar resiliency risks.
(4) An electric utility is required to maintain records
associated with the information referred to in this subsection for
five years, beginning the year after the plan is approved. Upon request
by commission staff an electric utility must provide any additional
information and updates on the status of the resiliency plan submitted.
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