Salt Lake City Area Integrated Projects-Rate Order No. WAPA-199, 61211-61219 [2021-24217]
Download as PDF
<![CDATA[
Federal Register / Vol. 86, No. 212 / Friday, November 5, 2021 / Notices
to the applicant’s request for blanket
authorization, under 18 CFR part 34, of
future issuances of securities and
assumptions of liability, is November
22, 2021.
The Commission encourages
electronic submission of protests and
interventions in lieu of paper, using the
FERC Online links at https://
www.ferc.gov. To facilitate electronic
service, persons with internet access
who will eFile a document and/or be
listed as a contact for an intervenor
must create and validate an
eRegistration account using the
eRegistration link. Select the eFiling
link to log on and submit the
intervention or protests.
Persons unable to file electronically
may mail similar pleadings to the
Federal Energy Regulatory Commission,
888 First Street NE, Washington, DC
20426. Hand delivered submissions in
docketed proceedings should be
delivered to Health and Human
Services, 12225 Wilkins Avenue,
Rockville, Maryland 20852.
In addition to publishing the full text
of this document in the Federal
Register, the Commission provides all
interested persons an opportunity to
view and/or print the contents of this
document via the internet through the
Commission’s Home Page (https://
www.ferc.gov) using the ‘‘eLibrary’’ link.
Enter the docket number excluding the
last three digits in the docket number
field to access the document. At this
time, the Commission has suspended
access to the Commission’s Public
Reference Room, due to the
proclamation declaring a National
Emergency concerning the Novel
Coronavirus Disease (COVID–19), issued
by the President on March 13, 2020. For
assistance, contact the Federal Energy
Regulatory Commission at
FERCOnlineSupport@ferc.gov or call
toll-free, (886) 208–3676 or TYY, (202)
502–8659.
Dated: November 1, 2021.
Debbie-Anne A. Reese,
Deputy Secretary.
[FR Doc. 2021–24262 Filed 11–4–21; 8:45 am]
BILLING CODE 6717–01–P
DEPARTMENT OF ENERGY
jspears on DSK121TN23PROD with NOTICES1
Western Area Power Administration
Salt Lake City Area Integrated
Projects—Rate Order No. WAPA–199
Western Area Power
Administration, DOE.
ACTION: Notice of rate order concerning
fixed firm power rates.
AGENCY:
VerDate Sep<11>2014
21:40 Nov 04, 2021
Jkt 256001
The fixed firm power rates for
the Salt Lake City Area Integrated
Projects (SLCA/IP) (Provisional Rates)
have been confirmed, approved, and
placed into effect on an interim basis.
Based on the FY 2021 financial toll on
the Upper Colorado River Basin Fund
(Basin Fund) and the drought-impacted
purchased power projections from the
Bureau of Reclamation (Reclamation)
August 2021 24-Month Study for FY
2022 and FY 2023 and the August 2021
Colorado River Simulation System
(CRSS) traces for FY 2024 through FY
2026, existing rates will not sustain a
balance in the Basin Fund capable of
supporting operations. The Colorado
River Storage Project Management
Center (CRSP MC) of the Western Area
Power Administration (WAPA) is
implementing a new SLCA/IP firm
power rate, effective December 1, 2021,
through December 31, 2023.
DATES: The Provisional Rates under Rate
Schedule SLIP–F12 are effective on the
first day of the first full billing period
beginning on or after December 1, 2021,
and will remain in effect through
December 31, 2023, pending
confirmation and approval by the
Federal Energy Regulatory Commission
(FERC) on a final basis or until
superseded.
SUMMARY:
Tim
Vigil, CRSP Manager, Colorado River
Storage Project Management Center,
Western Area Power Administration,
1800 South Rio Grande Avenue,
Montrose, CO 81401, or email:
CRSPMC-rate-adj-@wapa.gov, or
Thomas Hackett, Rates Manager, 801–
524–5503, or email: CRSPMC-rate-adj@
wapa.gov.
SUPPLEMENTARY INFORMATION: On
December 17, 2020, FERC confirmed
and approved Rate Schedules SLIP–F11
(SLCA/IP Firm Power), SP–NW5
(Network Integration Transmission
Service), SP–PTP9 (Firm Point-to-Point
Transmission Service), SP–NFT8 (NonFirm Point-to-Point Transmission
Service), SP–UU2 (Unreserved Use
Penalties), SP–EI5 (Energy and
Generator Imbalance Services), SP–
SSR5 (Operating Reserves—Spinning
and Supplemental Reserve Services),
and SP–SS1 (Sale of Surplus Products)
under Rate Order No. WAPA–190
(WAPA–190) on a final basis through
September 30, 2025.1
WAPA published a Federal Register
notice (Proposed FRN) on June 28, 2021
(86 FR 34002), proposing modifications
to only the firm power rate schedule
FOR FURTHER INFORMATION CONTACT:
1 Order Confirming and Approving Rate
Schedules on a Final Basis, FERC Docket No. EF20–
7–000, 173 FERC ¶ 61,230 (2020).
PO 00000
Frm 00099
Fmt 4703
Sfmt 4703
61211
(SLIP–F11) established under WAPA–
190. CRSP MC did not propose any
changes to the transmission and
ancillary services rate schedules
established under WAPA–190, and they
remain effective under WAPA–190
through September 30, 2025. The
Proposed FRN also initiated a public
consultation and comment period and
set forth the date and location of the
public information and public comment
forums.
WAPA is implementing the firm
power rate under Rate Schedule SLIP–
F12 to address worsening drought
conditions in the southwestern United
States and volatile purchased power
costs. The rates will go into effect
December 1, 2021, and remain in effect
until December 31, 2023, or until WAPA
supersedes or changes the rates through
another public rate process pursuant to
10 CFR part 903, whichever occurs first.
The CRSP MC is only implementing the
rate for 25 months to continue
collaborative conversations with
customers and interested parties on the
most effective use of available
generation and long-term strategies for
managing the cost of purchased power.
CRSP MC is basing FY 2022 and FY
2023 energy sales in the rate-setting
Power Repayment Study (PRS) on the
Reclamation August 2021 24-month
Study, and FY 2024 through FY 2026
sales on the CRSS traces and is forgoing
purchased power in the rates. Forgoing
purchased power decreased the
projected rate increase from 50 percent
to 11 percent. CRSP MC will not be
purchasing firming power to meet
Sustainable Hydropower (SHP) levels as
it has in the past. Calculated sales for
the effective period of the rate will be
limited to forecasted generation,
referred to as the Deliverable Sales
Amount (DSA). The DSA levels will be
updated quarterly and provided to
customers for power scheduling and
billing purposes. These quarterly
updates do not impact the rates. CRSP
MC will firm to the DSA level if
necessary. For those customers who
elect, CRSP MC will offer Western
Replacement Firming (WRF) purchased
power to customers, as a pass-through
cost at market rates, to firm to SHP
levels. Customers electing not to take
WRF will receive the DSA.
Legal Authority
By Delegation Order No. 00–037.00B,
effective November 19, 2016, the
Secretary of Energy delegated: (1) The
authority to develop power and
transmission rates to the WAPA
Administrator; (2) the authority to
confirm, approve, and place such rates
into effect on an interim basis to the
E:\FR\FM\05NON1.SGM
05NON1
61212
Federal Register / Vol. 86, No. 212 / Friday, November 5, 2021 / Notices
Deputy Secretary of Energy; and (3) the
authority to confirm, approve, and place
into effect on a final basis, or to remand
or disapprove such rates, to FERC. By
Delegation Order No. S1–DEL–S4–2021,
effective February 25, 2021, the Acting
Secretary of Energy also delegated the
authority to confirm, approve, and place
such rates into effect on an interim basis
to the Under Secretary for Science (and
Energy). By Redelegation Order No. S4–
DEL–OE1–2021, effective March 25,
2021, the Acting Under Secretary for
Science (and Energy) redelegated the
authority to confirm, approve, and place
such rates into effect on an interim basis
to the Assistant Secretary for Electricity.
By Redelegation Order No. 00–002.10–
05, effective July 8, 2020, the Assistant
Secretary for Electricity further
redelegated the authority to confirm,
approve, and place such rates into effect
on an interim basis to WAPA’s
Administrator. This redelegation order,
despite predating the February 2021 and
March 2021 delegations, remains valid.
This rate action is issued under
Redelegation Order No. 00–002.10–05
and Department of Energy procedures
for public participation in rate
adjustments set forth at 10 CFR part
903.1
Following review of CRSP MC’s
proposal, I hereby confirm, approve,
and place Rate Order No. WAPA–199,
which provides the fixed rates for firm
power, into effect on an interim basis.
WAPA will submit Rate Order No.
WAPA–199 to FERC for confirmation
and approval on a final basis.
By Delegation Order No. 00–037.00B,
effective November 19, 2016, the
Secretary of Energy delegated: (1) The
authority to develop power and
transmission rates to the Western Area
Power Administration’s (WAPA)
Administrator; (2) the authority to
confirm, approve, and place such rates
into effect on an interim basis to the
Deputy Secretary of Energy; and (3) the
authority to confirm, approve on a final
basis, remand, or disapprove such rates
to FERC. By Delegation Order No. S1–
DEL–S4–2021, effective February 25,
2021, the Acting Secretary of Energy
also delegated the authority to confirm,
approve, and place such rates into effect
on an interim basis to the Under
Secretary for Science (and Energy). By
Redelegation Order No. S4–DEL–OE1–
2021, effective March 25, 2021, the
Acting Under Secretary for Science (and
Energy) redelegated the authority to
confirm, approve, and place such rates
into effect on an interim basis to the
Assistant Secretary for Electricity. By
Redelegation Order No. 00–002.10–05,
effective July 8, 2020, the Assistant
Secretary for Electricity further
delegated the authority to confirm,
approve, and place such rates into effect
on an interim basis to WAPA’s
Administrator. This redelegation order,
despite predating the February 2021 and
March 2021 delegations remains valid.
This rate action is issued under
Redelegation Order No. 00–002.10–05
and DOE procedures for public
participation in rate adjustments set
forth at 10 CFR part 903.1
Department of Energy
The fixed rates in Rate Order No.
WAPA–199 are established following
section 302 of the Department of Energy
(DOE) Organization Act (42 U.S.C.
7152).1
Acronyms, Terms, and Definitions
As used in this Rate Order No.
WAPA–199, the following acronyms,
terms, and definitions apply:
Basin Fund: Upper Colorado River
Basin Fund.
Capacity: The electric capability of a
generator, transformer, transmission
circuit, or other equipment. It is
expressed in kilowatts (kW) or
megawatts (MW).
Capacity Rate: The rate which sets
forth the charges for capacity. It is
expressed in dollars per kilowatt-month
and applied to each kilowatt delivered
to each Customer.
CDP: Customer Displacement Power.
Composite Rate: The Power
Repayment Study (PRS) rate for
commercial firm power, which is the
total annual revenue requirement for
1 50 FR 37835 (Sept. 18, 1985) and 84 FR 5347
(Feb. 21, 2019).
1 This Act transferred to, and vested in, the
Secretary of Energy the power marketing functions
of the Secretary of the Department of the Interior
and the Bureau of Reclamation (Reclamation) under
the Reclamation Act of 1902 (ch. 1093, 32 Stat.
388), as amended and supplemented by subsequent
laws, particularly section 9(c) of the Reclamation
Project Act of 1939 (43 U.S.C. 485h(c)); and other
acts that specifically apply to the project(s)
involved.
1 50 FR 37835 (Sept. 18, 1985) and 84 FR 5347
(Feb. 21, 2019).
Administrator, Western Area Power
Administration
In the Matter of:
Western Area Power Administration,
Colorado River Storage Project
Management Center, Rate Adjustment
for the Salt Lake City Area, Integrated
Projects Fixed Firm Power Rates
Rate Order No. WAPA–199
jspears on DSK121TN23PROD with NOTICES1
Order Confirming, Approving, and
Placing the Salt Lake City Area
Integrated Projects Fixed Firm Power
Rates Into Effect on an Interim Basis
VerDate Sep<11>2014
21:40 Nov 04, 2021
Jkt 256001
PO 00000
Frm 00100
Fmt 4703
Sfmt 4703
capacity and energy divided by the total
annual energy sales. It is expressed in
mills per kilowatt-hour and used only
for comparison purposes.
CRC: Cost Recovery Charge.
CROD: Contract Rate of Delivery. The
maximum amount of capacity made
available to a preference Customer for a
period specified under a contract.
Customer: Firm electric service
customer(s) contractually receiving
SLCA/IP power and energy.
CY: Calendar Year. When used in the
CRC it is the 12-month period the CRC
is in effect.
DSA: Deliverable Sales Amount—
marketable generation level, above
which WAPA will forgo purchased
power.
Energy Rate: The rate which sets forth
the charges for energy. It is expressed in
mills/kWh and applied to each DSA
kWh delivered to each Customer.
Firm: A type of product or service
available at the time requested by the
Customer.
FY: Fiscal Year, October 1 to
September 30.
GWh: Gigawatt-hour—the electrical
unit of energy that equals 1 billion
watthours or 1 million kWh.
Integrated Projects: The resources and
revenue requirements of the Collbran,
Dolores, Rio Grande, and Seedskadee
projects blended with the CRSP to
create the SLCA/IP resources and rate.
kW: Kilowatt—the electrical unit of
capacity that equals 1,000 watts.
kWh: Kilowatt-hour—the electrical
unit of energy that equals 1,000 watts in
1 hour.
kWmonth: Kilowatt-month—the
electrical unit of the monthly amount of
capacity.
MAF: Million Acre-Feet. The amount
of gallons of water required to cover 1
million acres, 1 foot in depth.
Mill: A monetary denomination of the
United States that equals one tenth of a
cent or one thousandth of a dollar.
Mills/kWh: Mills per kilowatt-hour—
the unit of charge for energy.
MW: Megawatt—the electrical unit of
capacity that equals 1 million watts or
1,000 kilowatts.
MWh: One million watt-hours of
electric energy. A unit of electrical
energy which equals 1 megawatt of
power used for 1 hour.
NEPA: National Environmental Policy
Act of 1969, as amended.
OASIS: Open Access Same-Time
Information System—An electronic
posting system that a service provider
maintains for transmission access data
that allows all Customers to view
information simultaneously.
O&M: Operations and Maintenance.
OM&R: Operations, Maintenance and
Replacements.
E:\FR\FM\05NON1.SGM
05NON1
Federal Register / Vol. 86, No. 212 / Friday, November 5, 2021 / Notices
Power: Capacity and energy.
Project Use: Power used to operate
SLCA/IP and CRSP facilities under
Reclamation Law.
Provisional Rate: A rate confirmed,
approved, and placed into effect on an
interim basis by the Secretary or his/her
designee.
Rate Brochure: A document prepared
for public distribution explaining the
rationale and background for the
information contained in this rate order.
Ratesetting PRS: The Power
Repayment Study (PRS) used for the
rate adjustment period.
Revenue Requirement: The revenue
required to recover O&M expenses,
purchased power and transmission
service expenses, interest, deferred
expenses, and repayment of Federal
investments, or other assigned costs.
SHP: Sustainable Hydropower (longterm SLCA/IP hydro capacity with
energy).
SLCA/IP: Salt Lake City Area
Integrated Projects.
WL: Waiver Level.
Work Plan: An estimate of costs that
are expected to become the
Congressional Budget for WAPA and
Reclamation. Also known as a Work
Program.
WRF: Western Replacement Firming.
WRP: Western Replacement Power.
Effective Date
The Provisional Rate Schedule SLIP–
F12 will take effect on the first day of
the first full billing period beginning on
or after December 1, 2021, and will
remain in effect through December 31,
2023, pending approval by FERC on a
final basis or until superseded.
jspears on DSK121TN23PROD with NOTICES1
Public Notice and Comment
The CRSP MC followed the
Procedures for Public Participation in
Power and Transmission Rate
Adjustments and Extensions, 10 CFR
part 903, in developing these fixed rates.
Following are the steps CRSP MC took
to involve interested parties in the rate
process:
1. On June 28, 2021, a Federal
Register notice (86 FR 34002) (Proposal
FRN) announced the proposed rates and
launched the 65-day public consultation
and comment period. The comment
period was reduced from the customary
90-day period due to the $20 million
financial impact of not implementing
the rate by December 1, 2021.
2. On June 28, 2021, CRSP MC
notified Customers and interested
VerDate Sep<11>2014
21:40 Nov 04, 2021
Jkt 256001
parties of the proposed rates and
provided a copy of the published
Proposal FRN.
3. On July 7, 2021, CRSP MC held a
virtual public information forum. CRSP
MC representatives explained the
proposed fixed rates, answered
questions, and gave notice that more
information was available in the Rate
Brochure.
4. On July 28, 2021, CRSP MC held a
virtual public information forum on
purchased power and WRF. CRSP MC
representatives explained the process
used to project purchase power, how
WRF will be implemented, answered
questions, and gave notice that more
information would be available in a
subsequent version of the Rate Brochure
and provided points of contact for
additional questions on WRF
implementation.
5. On July 29, 2021, CRSP MC held a
virtual public information forum on the
CRC. CRSP MC representatives
explained the purpose of the CRC, the
need for changes, how it is calculated
and implemented, answered questions,
and gave notice that more information
was available in the Rate Brochure.
6. On August 11, 2021, CRSP MC held
a virtual public comment forum. This
provided Customers and other
interested parties an opportunity to
provide official comments for the
record.
7. On August 13, 2021, CRSP MC
posted responses to questions asked
during the August 11, 2021, virtual
public comment forum on the rate
action website and notified the
Customers and interested parties via
email.
8. CRSP MC provided a website that
contains all dates, Customer letters,
presentations, FRNs, Rate Brochure, and
other information about this rate
process. The rate action website is
located at www.wapa.gov/regions/CRSP/
rates/Pages/rate-order-199.aspx.
9. During the 65-day consultation and
comment period, which ended on
August 31, 2021, CRSP MC received 10
oral comments at the August 11, 2021,
virtual public comment forum, and
seven comment letters. All comments
from the virtual public comment forum
were addressed by WAPA via email
and/or responses were posted to the rate
action website on August 13, 2021. The
comments and CRSP MC responses are
addressed in the Comments section and
have been considered in the preparation
of this Rate Order No. WAPA–199.
PO 00000
Frm 00101
Fmt 4703
Sfmt 4703
61213
Oral comments were received from
the following organizations:
Colorado River Energy Distributors
Association (CREDA)
Utah Associated Municipal Power
Systems (UAMPS)
Arizona Electric Power Cooperative
(AEPCO)
Written comments were received from
the following organizations:
Colorado River Energy Distributors
Association (CREDA)
Arizona Electric Power Cooperative
(AEPCO)
Municipal Energy Agency of Nebraska
(MEAN/NMPP)
Platte River Power Authority (PRPA)
Tri-State Generation and Transmission
Association, Inc. (TRI–STATE)
Utah Rural Electric Cooperative
Association (URECA)
Utah Municipal Power Agency (UMPA)
10. CRSP MC received comments on
the original Rate Brochure. Comments
were addressed in subsequent versions
of the Rate Brochure.
11. CRSP MC provided a second
consultation and comment period from
September 22 through October 6, 2021.
This comment period facilitated
Customer feedback in reference to
purchased power and generation
updates. The comments and CRSP MC
responses are addressed in the
Comments section, and all comments
have been considered in the preparation
of this Rate Order No. WAPA–199.
Written comments were received from
the following organizations:
Colorado River Energy Distributors
Association (CREDA)
Platte River Power Authority (PRPA)
Power Repayment Study—Firm Power
Service Rate Discussion
CRSP MC prepares PRSs each FY to
determine if revenues will be sufficient
to repay, within the required time, all
costs assigned to the SLCA/IP.
Repayment criteria are based on
applicable laws and legislation, as well
as policies including DOE Order RA
6120.2. To meet the cost recovery
criteria outlined in DOE Order RA
6120.2, a revised PRS and rate
adjustment have been developed to
demonstrate that sufficient revenues
will be collected under the Provisional
Rate to meet future obligations. The
revenue requirement and composite rate
for SLCA/IP firm power service are
being increased, as indicated in Table 1:
E:\FR\FM\05NON1.SGM
05NON1
61214
Federal Register / Vol. 86, No. 212 / Friday, November 5, 2021 / Notices
TABLE 1—COMPARISON OF REVENUE REQUIREMENTS AND COMPOSITE RATES
Existing requirements
(October 1, 2020)
Firm power service
Revenue Requirement (million $) ................................................................
Composite Rate (mills/kWh) ........................................................................
Under the existing rate methodology,
rates for firm power service are designed
to recover an annual revenue
requirement that includes power
investment repayment, aid to irrigation
repayment, interest, O&M,
replacements, and other expenses
within the allowable period.
Firm Power Service—Existing and
Provisional Rates
CRSP MC is implementing this rate
action primarily in response to a large
increase in purchased power costs due
Provisional requirements
(December 1, 2021)
$173.511
27.45
to worsening drought conditions in the
southwestern United States and an
increase to OM&R expenses.
CRSP MC is basing sales in the rate on
forecasted generation in Reclamation’s
August 2021 24-month Study for the
effective period of the rate and is
subsequently forgoing purchased power
in the Ratesetting PRS. Forgoing
purchased power mitigates the projected
rate increase from 50-percent down to
11-percent. CRSP MC will not
automatically purchase firming power
to SHP levels. For those Customers who
$181,197
30.51
Percent
change
+4.4
+11.1
elect, CRSP MC will purchase WRF
power as a pass-through cost, at market
rates, up to SHP levels. CRSP MC will
purchase power to firm to the forecasted
generation level, referred to as the DSA.
The DSA will be updated quarterly as
shown in Table 2. Customers will have
at least 14 days to affirmatively select
WRF for each quarter. Quarterly notices
provide flexibility in responding to
changes in hydrology and will not
impact the rates. Customers can elect
the full quarter or specific months
within the quarter.
TABLE 2—QUARTERLY DSA ADJUSTMENT SCHEDULE
Quarter impacted
Reclamation 24-month study
Notify customers by:
December 2021 .................................................
January–March 2022 .........................................
April–June 2022 .................................................
July–September 2022 ........................................
October–December 2022 ..................................
January–March 2023 .........................................
April–June 2023 .................................................
July–September 2023 ........................................
October–December 2023 ..................................
August 2021 .....................................................
November 2021 ................................................
February 2022 ..................................................
May 2022 ..........................................................
August 2022 .....................................................
November 2022 ................................................
February 2023 ..................................................
May 2023 ..........................................................
August 2023 .....................................................
mid-October 2021.
Est: November 20, 2021.
Est: February 20, 2022.
Est: May 20, 2022.
Est: August 20, 2022.
Est: November 20, 2022.
Est: February 20, 2023.
Est: May 20, 2023.
Est: August 20, 2023.
CRSP MC provided information on
the implementation process of the WRF
and DSA in the Rate Brochure, at the
virtual public information forum, at a
virtual purchased power forum, and
replied to questions from the virtual
public comment forum via email. This
information was published on the rate
action website at: www.wapa.gov/
regions/CRSP/rates/Pages/rates.aspx.
A comparison of the existing and
provisional rates for firm power service
is listed in Table 3. The Provisional Rate
is a fixed rate that will go into effect
December 1, 2021, and remain in effect
through December 31, 2023, or until
WAPA supersedes or changes the rates
through another public rate process
pursuant to 10 CFR part 903, whichever
occurs first.
TABLE 3—COMPARISON OF EXISTING AND PROVISIONAL RATE
Firm power service
Existing charges
under rate schedule
SLIP–F11 as of
October 1, 2020
Provisional charges
under rate schedule
SLIP–F12 as of
December 1, 2021
11.43
4.85
12.36
5.25
Firm Energy Rate (mills/kWh) .............................................................................
Firm Capacity Rate ($/kWmonth) ........................................................................
Statement of Revenue and Related
Expenses
jspears on DSK121TN23PROD with NOTICES1
Table 4 provides a comparison of the
average annual expense data for the firm
power service revenue requirement
through the rate-setting period. The
purchase power shown in the table
reflects purchase power costs for
October and November 2021 that fall
Percent change
+8.1
+8.3
under the SLIP F11 rates. There is no
projected purchase power amount
included in the rate for service from
December 2021 through December 2026.
TABLE 4—ANNUAL REVENUE REQUIREMENTS AND FIRM POWER RATES COMPARISON TABLE
Existing rate
($000)
Rate Setting Period .........................................................................................................
VerDate Sep<11>2014
21:40 Nov 04, 2021
Jkt 256001
PO 00000
Frm 00102
Fmt 4703
Sfmt 4703
Provisional rate
($000)
2021–2038
E:\FR\FM\05NON1.SGM
2022–2045
05NON1
Difference
($000)
61215
Federal Register / Vol. 86, No. 212 / Friday, November 5, 2021 / Notices
TABLE 4—ANNUAL REVENUE REQUIREMENTS AND FIRM POWER RATES COMPARISON TABLE—Continued
Existing rate
($000)
Provisional rate
($000)
Difference
($000)
Revenue Distribution:
Expenses:
O&M ..................................................................................................................
Purchase Power ................................................................................................
Transmission .....................................................................................................
Integrated Projects requirements ......................................................................
Interest ...............................................................................................................
Other ..................................................................................................................
$97,352
1,119
8,998
6,485
6,066
17,909
$103,095
833
8,984
7,043
6,207
13,547
$5,743
(286)
(14)
558
141
(4,362)
Total Expenses ..........................................................................................
137,928
139,709
1,781
Principal Payments:
Capitalized Expenses (deficits) .........................................................................
Replacements ....................................................................................................
Original Project and Additions ...........................................................................
Irrigation .............................................................................................................
0
26,918
2,484
6,181
838
29,581
1,846
9,223
838
2,663
(638)
3,042
Total Principal Payments ...........................................................................
35,583
41,488
5,905
Annual Revenue Requirement ...................................................................
173,511
181,197
7,686
The rates would provide sufficient
revenue to recover annual O&M
expenses, replacement expenses,
interest expense, irrigation assistance,
and capital repayment requirements
within the cost recovery criteria set
forth in Department of Energy (DOE)
Order No. RA 6120.2.
Purchased power required to
supplement hydropower deliveries up
to contractual levels will be passed
through to Customers under a separate
charge, WRF, which would be in
addition to the rate for hydropower
deliveries. Any Customer not receiving
WRF will not be charged the purchased
power charge and would receive its
proportionate amount of the DSA
capacity and energy from WAPA each
month.
SLCA/IP Firm Power Rate
The revenue requirement for Rate
Schedule SLIP–F12 is based on current
data available, specifically the FY 2020
historical financial data, FY 2022 Work
Plan for WAPA, FY 2023 Work Plan for
Reclamation, and Reclamation’s August
2021 24-Month Study (24-month Study)
and Colorado River Simulation System
(CRSS) traces.
Under rate schedule SLIP–F12,
WAPA will use the Reclamation August
2021 24-Month Study to determine
generation and projected sales for the 2
rate years (FYs 22–23) and CRSS for FYs
24–26 of the rate-setting period.
Additionally, the rate schedule includes
actions WAPA will take should Lake
Powell’s water level drop below the
level at which power can be generated.
Cost Recovery Charge
WAPA will retain the CRC as a
mechanism to use, if necessary, to
adequately recover and maintain a
sufficient balance in the Basin Fund in
the event projected expenses
significantly exceed projected revenue
estimates. The Basin Fund is a revolving
fund that operates using CRSP MC
power revenues without annual
appropriations. The CRC is an
additional surcharge on all long-term
energy sales provided under the WAPA
SLCA/IP firm electric service contracts.
The CRC may be implemented when,
among other things, the Basin Fund
cash balance is at risk due to low
hydropower generation, high prices for
firming power, or emergency capitalized
investment funding. The CRC is
independent of the SLCA/IP PRS
calculations.
WAPA reserves the right to
implement a CRC at any point
throughout the year using guidance
from the existing implementation
criteria in Table 5 and the latest 24month Study from Reclamation. An
established CRC would be in effect for
12 months from the date implemented.
If circumstances dictate the need to
reassess an established CRC, the
updated CRC will supersede the
previous CRC and remain in effect for
12 months. The CRC is implemented at
WAPA’s discretion based on the balance
of the Basin Fund and WAPA’s ability
to meet contractual requirements. The
minimum Basin Fund carryover balance
is $40 million.
TABLE 5—CRC IMPLEMENTATION TIERS
Tier
i ................
ii ................
jspears on DSK121TN23PROD with NOTICES1
iii ...............
iv ...............
v ...............
VerDate Sep<11>2014
Criteria, if the basin fund beginning balance is:
Notification
Greater than $150 million with an expected decrease to below $75 million ......................................
Less than $150 million but greater than $120 million with an expected 50-percent decrease in the
next CY.
Less than $120 million but greater than $90 million with an expected 40-percent decrease in the
next CY.
Less than $90 million but greater than $60 million with an expected 25-percent decrease in the
next CY.
Less than $60 million but greater than $40 million with an expected decrease to below $40 million
in the next CY.
21:40 Nov 04, 2021
Jkt 256001
PO 00000
Frm 00103
Fmt 4703
Sfmt 4703
E:\FR\FM\05NON1.SGM
05NON1
Annually (July).
Semi-Annual (July/January).
Monthly.
61216
Federal Register / Vol. 86, No. 212 / Friday, November 5, 2021 / Notices
WAPA reserves the right to
implement a CRC throughout the year if
annual water releases from Glen Canyon
Dam fall below 8.23 MAF, regardless of
the Basin Fund balance.
If a CRC is implemented, CRSP MC
will establish an energy Waiver Level
(WL) using the CRC formula. Customers
could accept either the CRC or WL. The
WL provides WAPA the ability to
reduce purchase power expenses by
delivering less energy than its
contractual obligations. For those
Customers who agree to schedule no
more energy than their proportionate
share of the WL, WAPA would waive
the CRC for that year.
If, in any month, the annual water
release volumes from Glen Canyon Dam
return to 8.23 MAF or higher while a
CRC is in place, a new CRC will be
calculated for the next month, and each
Customer will be notified of the
recalculated CRC results.
CRC sample calculations, narratives,
and schedules are located on the CRC
web page: www.wapa.gov/regions/
CRSP/rates/Pages/cost-recoverycharge.aspx.
Comments
CRSP MC received 52 oral or written
comments during the public
consultation and comment period. The
comments expressed have been
paraphrased or consolidated, where
appropriate, without compromising the
meaning of the comments.
jspears on DSK121TN23PROD with NOTICES1
Comments on Firm Power Rates
A. Comment: Commentor urged
WAPA to continue to refine elements
other than purchased power in the PRS
to result in the lowest possible rate,
consistent with sound business
principles.
Response: CRSP MC analyzed data
including O&M work plans, 10-year
plans for capital investment, and
Customer agreements, as well as
Customer input, to ensure rates are the
lowest possible consistent with sound
business principles.
B. Comment: Commentor requested
that WAPA continue to reflect ‘‘expense
reductions to the work plans as they
become available,’’ until the latest
possible date, as those work plan-related
discussions are still underway.
Response: CRSP MC incorporated
changes to the Reclamation and WAPA
work plan reviews into the power
repayment study as the information was
made available including using WAPA’s
FY 22 Work Plan instead of the FY 23
Work Plan. CRSP MC updated
supporting data documents and posted
them to the rate action website and
VerDate Sep<11>2014
21:40 Nov 04, 2021
Jkt 256001
included the results in the Rate
Brochure updates.
C. Comment: Multiple commentors
asked about the availability of firm
transmission for Customers who do not
elect WRF and what CRSP MC will do
with surplus transmission.
Response: The CROD capacity will
not be reduced. Available capacity up to
the CROD is available for Customer use
as WRP and CDP as provided in the
Customers’ SLCA/IP firm electric
service contracts. Surplus transmission,
if any, would be made available through
the OASIS based on existing policy and
procedures.
D. Comment: Commentor expressed
concerns over ‘‘rate shock’’ for small
Customers and stated the rate process
provides very little time for Customers
to design and implement retail rate
adjustments that account for these
changes. Commentor believes WAPA
must consider this rate shock and what
(if any) new value WAPA can provide
to help offset this significant increase.
Response: CRSP MC understands that
increasing rates impacts its Customers.
CRSP MC operates on a cost-basis and
must establish rates to collect sufficient
revenue to meet operational expense
and repayment obligations. Significant
increases in purchase power costs
warrant the need for the rate action.
CRSP MC followed public notice
requirements of the Administrative
Procedure Act in setting forth this
proposed rate change. CRSP MC
implemented this short rate period so
collaborative conversations with
interested parties could occur over the
next 2 years on the most effective use
of available generation and long-term
strategies for managing the cost of
purchased power.
Comments on Services
A. Comment: Commentor believes
WAPA’s Customers must have the
ability to convert some of their
allocation into ancillary services to
offset the financial impacts of the rate
increase.
Response: All available energy is
committed to firm power service
deliveries.
B. Comment: One commentor asked
WAPA to clarify whether the firm
capacity and energy will be restored to
Customers in the event the Colorado
River Basin’s hydrological conditions
revert to historical levels.
Response: Should forecasted
hydrological conditions improve, the
DSA levels will rise providing
additional energy allocations for
Customers. AHP as defined in the
SLCA/IP firm electric service contract
will also be offered if hydrological
PO 00000
Frm 00104
Fmt 4703
Sfmt 4703
conditions improve significantly within
an established quarter.
C. Comment: One commentor does
not agree with WAPA’s position that the
‘‘Tribe under the benefit crediting
contract would need to decide whether
to receive WRF and communicate that
decision to its benefit crediting utility.’’
Commentor’s position is the election of
WRF should be that of the benefit
crediting utility, not the Tribe.
Response: CRSP MC has clarified this
issue. WRF may be selected by the
utility providing the benefit crediting
service. This is like the existing
treatment under the WRP program. The
benefit crediting amount provided to a
Tribe is to be calculated on the Tribe’s
hydropower delivery amounts.
D. Comment: Commentor asked that
WAPA ensure participants retain the
option to independently purchase
replacement power to cover shortfalls in
CRSP production. The proposed opt-in
process should be, at most, seasonal
(every 6 months) to prevent adverse
selection issues or last-minute decisions
by individual members that change
market conditions for all project
participants.
Response: Customers can
independently use their own resources
or purchase their own firming power
under the CDP program. To provide
greater flexibility in responding to
hydrology, CRSP MC has enhanced the
DSA and WRF programs by using
quarterly notices to the Customers.
Although 6-month periods were
originally proposed, Customers
requested additional flexibility in
determining which months to
potentially purchase WRF. Quarterly
notices will provide Customers
additional flexibility in meeting their
resource needs and provide CRSP MC
more certainty about water releases and
hydropower generation availability.
E. Comment: Commentor asked that
WAPA protect preference Customers’
firm transmission rights, so Customers
can use their transmission rights for
power delivered to make up for power
WAPA cannot provide. Commentor
asked that WAPA maintain the current
practice for firm transmission for power
delivered in lieu of WAPA power,
which was implemented earlier in this
ongoing drought.
Response: Available capacity up to
the CROD is still available for Customer
use as WRP and CDP.
Comments in Support
A. Comment: Multiple commentors
provided favorable comments thanking
WAPA for its willingness to collaborate
through rate, resource, and work plan
processes; inclusion of two topical
E:\FR\FM\05NON1.SGM
05NON1
Federal Register / Vol. 86, No. 212 / Friday, November 5, 2021 / Notices
jspears on DSK121TN23PROD with NOTICES1
virtual public forums to assist in
Customer review and understanding of
the WAPA–199 rate; appreciation for
WAPA’s Customer notification of
materials being posted on the rate
website; appreciation for WAPA’s
willingness to work with them to
improve the capability and accessibility
of the modeling tools used to analyze
and produce CRSP rate scenarios in a
timely manner; appreciation for
WAPA’s flexibility in providing a 14day consultation and comment period
after ‘‘final purchased power amounts’’
have been posted to its website;
appreciation towards WAPA, CRSP
staff, and Reclamation’s work with
Customers during this rate process and
through the process referred to as the
‘‘work program review’’ process.
Response: CRSP MC appreciates the
feedback and recognizes the benefits of
collaborating with Customers and
interested parties.
B. Comment: Two commentors
expressed appreciation for CRSP MC’s
and Upper Colorado Region of
Reclamation’s approach to mitigating
drought impacts and ensuring that the
Basin Fund remains viable through the
new rate components and continuation
of the WRP and CDP processes, as well
as the PRS and rates.
Response: CRSP MC appreciates the
feedback.
C. Comment: Commentor expressed
support for the revisions made to the
CRC described in the Rate Brochure.
Response: CRSP MC appreciates the
feedback on the CRC revisions.
Comments on Customer
Communications
A. Comment: Two commentors
requested WAPA continue timely
communication, collaboration, and
transparency with CRSP Customers on
decisions, ongoing concerns, and
potential impacts of recent Senate
infrastructure funding.
Response: While the Senate
infrastructure funding is out of scope for
this rate action, CRSP MC understands
the benefits of communication,
collaboration, and transparency with its
Customers in addressing potential rate
impacts.
B. Comment: One commentor
requested WAPA incorporate
information/adjustments from pending
Reclamation and WAPA reviews into
the final proposed/provisional rate, and
the results of that inclusion be provided
to them.
Response: CRSP MC incorporated
changes tied to the Reclamation and
WAPA work plan reviews into the PRS
as the information was made available.
CRSP MC updated supporting data
VerDate Sep<11>2014
21:40 Nov 04, 2021
Jkt 256001
documents, posted them to the rate
action website, and included the results
in the Rate Brochure updates.
C. Comment: One commentor
requested WAPA ensure Customers are
notified of the Provisional Rate under
this rate order prior to the issuance of
Customer Notification of the DSA
Season Update for Winter 2022 Season.
Response: CRSP MC provided the
projected final rate on September 22,
2021, when it opened the Customer
Comment Period on Purchased Power
and Generation. The rate was
subsequently decreased based on
changes to project use power and CRSP
MC’s decision to use the FY 2022 work
plan for the rate-setting period to reduce
costs.
D. Comment: Commenter requested
their most recent correspondence be
included in the WAPA–199 record.
Response: CRSP MC filed all received
comments in the decision of record for
this rate process.
E. Comment: One commentor asked
WAPA to continue its practice of
collaboration and transparency for
future decisions that affect CRSP
Customers, such as costs for shaping
and firming services as additional
power is needed to maintain reliable
supply.
Response: CRSP MC will continue its
practice of collaboration and
transparency.
Comments on Other
A. Comment: Commentor expressed
recognition of the significance of the
current drought conditions in the
Colorado River Basin and the challenges
that are being presented to WAPA and
the CRSP Customers.
Response: CRSP MC appreciates the
feedback.
B. Comment: One commentor
expressed appreciation that the current
scope of this rate order does not propose
changes to ancillary services.
Commentor wants any future changes to
ancillary services to be part of a separate
rulemaking.
Response: The current transmission
and ancillary service formula rates
established under Rate Order WAPA–
190 required no modifications and
continue to be effective under Rate
Order WAPA–190 through September
30, 2025.
Second Comment Period Comments
A. Comment: Commenters expressed
that it does not make sense to apply the
CRC to all SHP and DSA because DSA
is a subset of SHP.
Response: CRSP MC concurs. Since
CRSP MC is only purchasing firming
power to the DSA level, instances of
PO 00000
Frm 00105
Fmt 4703
Sfmt 4703
61217
SHP in the CRC will be replaced with
DSA in the FRN and supporting
documentation.
B. Comment: Commenters expressed
that the CRC does not belong in the
WRF cost recovery equation.
Response: CRSP MC concurs that
WRF is exempt from the CRC
calculation. The CRC only applies to the
firming purchases up to the DSA level.
C. Comment: Commenter said,
‘‘Because any portion of a customer’s
SHP above DSA will necessarily be
WRF, the CRC should not apply to the
above-DSA amount.’’
Response: CRSP MC concurs that the
CRC only applies to firming purchases
up to the DSA level and made
conforming changes within the FRN and
supporting documentation.
D. Comment: Commenter thanks
WAPA for the additional comment
period to respond to updated elements
of its CRSP rate proposal, and for its
continuing commitment to transparency
and collaboration in the rate-setting
process.
Response: WAPA appreciates the
feedback.
E. Comment: Commenter supports
WAPA making ‘‘additional changes to
the work plan’’ . . . and including them
in the final rate package without ‘‘an
additional comment period for
Customer review.’’
Response: The WAPA decision not to
initiate an additional comment period
was due to the changes decreasing the
proposed rate. Had the recent update to
the workplan increased the proposed
rate, WAPA would have considered an
additional comment period or delayed
implementation of the change until the
next rate action.
F. Comment: Commenter supports the
change in the DSA and WRF to
quarterly time frames, and the addition
that Customers may elect specific
months within the quarter, to receive
WRF.
Response: CRSP MC appreciates the
feedback.
G. Comment: Commenter urges
ongoing customer collaboration to
address hydrologic conditions and
forecasts, Basin Fund targets (including
any methodology changes which may be
made), MOA transfer timing, non-power
program and non-reimbursable funding
and Congressional action.
Response: CRSP MC recognizes the
benefits of customer collaboration in
dealing with the drought and impacts
on generation and the energy rates.
CRSP MC will continue its practice of
transparency by providing information
as it becomes available.
H. Comment: Commenter supports the
collaborative effort WAPA has made
E:\FR\FM\05NON1.SGM
05NON1
61218
Federal Register / Vol. 86, No. 212 / Friday, November 5, 2021 / Notices
with Customers to develop long-term
solutions to manage revenue
requirements and cash flow.
Response: WAPA appreciates the
feedback and recognizes the benefits of
customer collaboration.
Certification of Rates
I have certified that the Provisional
Rates for SLCA/IP Firm Power under
Rate Schedule SLIP–F12 are the lowest
possible rates, consistent with sound
business principles. The Provisional
Rates were developed following
administrative policies and applicable
laws.
Availability of Information
Information about this rate
adjustment, including the Rate
Brochure, PRSs, comments, letters,
memoranda, and other supporting
materials that were used to develop the
Provisional Rates, is available for
inspection and copying at the Colorado
River Storage Project Management
Center Office, 1800 South Rio Grande
Avenue, Montrose, CO. Many of these
documents are also available on
WAPA’s website at www.wapa.gov/
regions/CRSP/rates/Pages/rates.aspx, or
email; CRSPMC-rate-adj@wapa.gov.
Ratemaking Procedure Requirements
Environmental Compliance
jspears on DSK121TN23PROD with NOTICES1
WAPA has determined this action fits
within the following categorical
exclusions listed in appendix B to
subpart D of 10 CFR part 1021.410: B4.3
(Electric power marketing rate changes)
and B4.4 (Power marketing services and
activities). Categorically excluded
projects and activities do not require
preparation of either an environmental
impact statement or an environmental
assessment.1 Specifically, WAPA has
determined that this rulemaking is
consistent with activities identified in
B4, Categorical Exclusions Applicable to
Specific Agency Actions (see 10 CFR
part 1021, appendix B to subpart D, part
B4). A copy of the categorical exclusion
determination is available on WAPA’s
website at: www.wapa.gov/regions/
CRSP/environment/Pages/
environment.aspx.
clearance of this notice by the Office of
Management and Budget is required.
Submission to the Federal Energy
Regulatory Commission
The Provisional Rate herein
confirmed, approved, and placed into
effect on an interim basis, together with
supporting documents, will be
submitted to FERC for confirmation and
final approval.
Order
In view of the above, and under the
authority delegated to me, I hereby
confirm, approve, and place into effect,
on an interim basis, Rate Order No.
WAPA–199. The rates will remain in
effect on an interim basis until: (1) FERC
confirms and approves them on a final
basis; (2) subsequent rates are confirmed
and approved; or (3) such rates are
superseded.
Signing Authority
This document of the Department of
Energy was signed on October 28, 2021,
by Tracey LeBeau, Administrator,
Western Area Power Administration,
pursuant to delegated authority from the
Secretary of Energy. That document,
with the original signature and date, is
maintained by DOE. For administrative
purposes only, and in compliance with
requirements of the Office of the Federal
Register, the undersigned DOE Federal
Register Liaison Officer has been
authorized to sign and submit the
document in electronic format for
publication, as an official document of
the Department of Energy. This
administrative process in no way alters
the legal effect of this document upon
publication in the Federal Register.
Signed in Washington, DC, on November 2,
2021.
Treena V. Garrett
Federal Register Liaison Officer, U.S.
Department of Energy.
Rate Schedule SLIP–F12
(Supersedes Rate Schedule SLIP–F11)
United States Department of Energy
Western Area Power Administration
Determination Under Executive Order
12866
Colorado River Storage Project
Management Center Salt Lake City
Area Integrated Projects
WAPA has an exemption from
centralized regulatory review under
Executive Order 12866; accordingly, no
Schedule of Rates for Firm Power
Service (Approved Under Rate Order
No. WAPA–199)
1 The
determination was done in compliance with
NEPA (42 U.S.C. 4321–4347); the Council on
Environmental Quality Regulations for
implementing NEPA (40 CFR parts 1500–1508); and
DOE NEPA Implementing Procedures and
Guidelines (10 CFR part 1021).
VerDate Sep<11>2014
21:40 Nov 04, 2021
Jkt 256001
Effective: The first day of the first full
billing period beginning on or after
December 1, 2021, and extending
through December 31, 2023, or until
superseded by another rate schedule,
whichever occurs earlier.
PO 00000
Frm 00106
Fmt 4703
Sfmt 4703
Available: In the area served by the
Salt Lake City Area Integrated Projects.
Applicable: To the wholesale power
Customer for firm power service
supplied through one meter at one point
of delivery or as otherwise established
by contract.
Character: Alternating current, 60
hertz, three-phase, delivered and
metered at the voltages and points
established by contract.
Monthly Rate: Demand Charge: $5.25
per kilowatt of billing demand.
Energy Charge: $12.36 mills per
kilowatthour of use of Deliverable Sales
Amount (DSA) energy.
Modification of Purchased Power:
WAPA will not automatically provide
purchased power to firm to SHP energy
allocations, nor will there be any
purchased power costs under Rate
Order WAPA–199 in the rate setting
period in the power repayment study
under Rate Order WAPA–199. WAPA
will establish the rates using the
projected DSA data in the Bureau of
Reclamation’s (Reclamation) August
2021 24-month Study and Reclamation’s
August 2021 Colorado River Simulation
System traces.
Western Replacement Firming (WRF):
WRF applies to pass-through purchased
power costs for energy provided
between the DSA level and SHP energy
allocation. WRF is an optional product.
Customers must elect quarterly, and
may elect specific months within the
quarter, to receive WRF. The charge for
this purchased power will be
determined at the time of the purchase
based on market rates. There are no
losses or an administrative fee charged
to WRF. A schedule for the quarterly
updates is in the rate brochure on the
rate action website: www.wapa.gov/
regions/CRSP/rates/Pages/rates.aspx.
Billing Demand: The billing demand
will be the greater of:
1. The highest 30-minute integrated
demand measured during the month up
to, but not more than, the delivery
obligation under the power sales
contract, or,
2. The Contract Rate of Delivery.
Billing Energy: The billing energy will
be the energy measured during the
month up to, but not more than, the
delivery obligation under the power
sales contract.
Adjustment for Transformer Losses: If
delivery is made at transmission voltage
but metered on the low-voltage side of
the substation, the meter readings will
be increased to compensate for
transformer losses as provided in the
contract.
Adjustment for Power Factor: The
Customer will be required to maintain a
power factor at all points of
E:\FR\FM\05NON1.SGM
05NON1
61219
Federal Register / Vol. 86, No. 212 / Friday, November 5, 2021 / Notices
measurement between 95 percent
lagging and 95 percent leading.
Adjustment for Western Replacement
Power (WRP): Pursuant to the
Customer’s Firm Electric Service
Contract, as amended, WAPA will bill
the Customer for its proportionate share
of the costs of WRP within a given time.
WAPA will include in the monthly
power bill the cost of the WRP, and the
incremental administrative costs
associated with WRP.
Adjustment for Customer
Displacement Power (CDP)
Administrative Charges: WAPA will
include in the Customer’s regular
monthly power bill the incremental
administrative costs associated with
CDP.
Adjustment for Minimum Power Pool:
If Lake Powell drops below ‘‘minimum
power pool’’ and power cannot be
generated, WAPA will provide 30 days’
notice to the Customers prior to
reducing the DSA.
Cost Recovery Charge (CRC): To
adequately recover and maintain a
sufficient balance in the Basin Fund,
WAPA uses a cost recovery mechanism,
called a CRC. The CRC is a charge on
all long-term energy sales provided
under WAPA’s SLCA/IP firm electric
service contracts.
This charge will be, at a minimum,
recalculated before July 1 of each year,
and WAPA will provide notification to
the Customers consistent with the
procedures in 10 CFR 903. WAPA has
the discretion to implement the CRC at
any point throughout the year using the
criteria in Table 1. The charge, if
needed, will be placed into effect on the
first day of the first full-billing period
beginning on or after the first day of the
month the CRC is implemented. For the
purposes of the CRC, the 12-month
period of a CRC will be described as a
calendar year (CY). The CRC will be
calculated as follows:
TABLE 1—CRC TIERS
Tier
i ...................
ii ..................
iii .................
iv .................
v ..................
Criteria, if the basin fund beginning balance (BFBB) is:
Greater than $150 million, with an expected decrease to below $75 million ............................
Less than $150 million but greater than $120 million, with an expected 50 percent decrease
in the next CY.
Less than $120 million but greater than $90 million, with an expected 40 percent decrease
in the next CY.
Less than $90 million but greater than $60 million, with an expected 25 percent decrease in
the next CY.
Less than $60 million but greater than $40 million with an expected decrease to below $40
million in the next CY.
CRC sample calculations, narratives,
and schedules showing the dates for
implementing a CRC throughout the
year are located at the CRC web page:
www.wapa.gov/regions/CRSP/rates/
Pages/cost-recovery-charge.aspx.
Waiver Level (WL)
jspears on DSK121TN23PROD with NOTICES1
WAPA will establish a WL that
provides WAPA the ability to reduce
purchased power expenses by
scheduling less energy than what is
contractually required. Therefore, for
those Customers who voluntarily
schedule no more energy than their
proportionate share of the WL, WAPA
will waive the CRC for that year. After
the Funds Available have been
determined, the WL will be set at the
sum of the energy that can be provided
through hydro generation and
purchased with Funds Available. The
WL will not be less than the forecasted
Hydro Energy.
Trigger for Water Release Criteria: In
the event that Reclamation’s 24-month
study projects Glen Canyon Dam water
releases will drop below 8.23 million
VerDate Sep<11>2014
Notification
21:40 Nov 04, 2021
Jkt 256001
acre feet (MAF) in a water year (October
through September), WAPA will
recalculate the CRC to include those
lower estimates of hydropower
generation. WAPA, as in the yearly
projection for the CRC, will give the
Customers a 45-day notice to request a
waiver of the CRC if they do not want
to have the CRC charge added to their
energy bills. This recalculation will
remain in effect for the remainder of the
CY.
If the annual water release volumes
from Glen Canyon Dam return to 8.23
MAF or higher during the trigger
implementation, a new CRC will be
calculated for the next month, and the
Customer will be notified.
Trigger for New Rate Criteria
WAPA would reassess an
implemented CRC when a new rate goes
into effect to determine if the
implemented CRC should be continued,
superseded, or terminated.
Prior Year Adjustment for CRC: Since
the annual determination of the CRC is
based upon estimates, an annual, prior-
PO 00000
Frm 00107
Fmt 4703
Sfmt 9990
Annually (July).
Semi-Annual (July/January).
Monthly.
year adjustment (PYA) will be
calculated for those who did not elect
the waiver level. The PYA will be based
on the 12-month period the CRC was in
effect.
The Customers’ PYA will be based on
their prior 12-months’ energy multiplied
by the PYA mills/kWh to determine the
dollar value that will be assessed. The
Customer will be charged or credited for
this dollar amount equally in the
remaining months of the next 12-month
billing cycle. WAPA will complete this
calculation within 2 months of the end
of the CRC. Therefore, if the PYA is
calculated in June, the charge/credit
will be spread over the remaining 9
months of the CY (July through March).
Adjustment for CRC Waiver:
Customers can choose not to take the
full DSA energy supplied as determined
in the attached formulas for CRC and
will be billed the Energy and Capacity
rates listed above, but not the CRC.
[FR Doc. 2021–24217 Filed 11–4–21; 8:45 am]
BILLING CODE 6450–01–P
E:\FR\FM\05NON1.SGM
05NON1
]]>Agencies
[Federal Register Volume 86, Number 212 (Friday, November 5, 2021)]
[Notices]
[Pages 61211-61219]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 2021-24217]
-----------------------------------------------------------------------
DEPARTMENT OF ENERGY
Western Area Power Administration
Salt Lake City Area Integrated Projects--Rate Order No. WAPA-199
AGENCY: Western Area Power Administration, DOE.
ACTION: Notice of rate order concerning fixed firm power rates.
-----------------------------------------------------------------------
SUMMARY: The fixed firm power rates for the Salt Lake City Area
Integrated Projects (SLCA/IP) (Provisional Rates) have been confirmed,
approved, and placed into effect on an interim basis. Based on the FY
2021 financial toll on the Upper Colorado River Basin Fund (Basin Fund)
and the drought-impacted purchased power projections from the Bureau of
Reclamation (Reclamation) August 2021 24-Month Study for FY 2022 and FY
2023 and the August 2021 Colorado River Simulation System (CRSS) traces
for FY 2024 through FY 2026, existing rates will not sustain a balance
in the Basin Fund capable of supporting operations. The Colorado River
Storage Project Management Center (CRSP MC) of the Western Area Power
Administration (WAPA) is implementing a new SLCA/IP firm power rate,
effective December 1, 2021, through December 31, 2023.
DATES: The Provisional Rates under Rate Schedule SLIP-F12 are effective
on the first day of the first full billing period beginning on or after
December 1, 2021, and will remain in effect through December 31, 2023,
pending confirmation and approval by the Federal Energy Regulatory
Commission (FERC) on a final basis or until superseded.
FOR FURTHER INFORMATION CONTACT: Tim Vigil, CRSP Manager, Colorado
River Storage Project Management Center, Western Area Power
Administration, 1800 South Rio Grande Avenue, Montrose, CO 81401, or
email: [email protected], or Thomas Hackett, Rates Manager,
801-524-5503, or email: [email protected].
SUPPLEMENTARY INFORMATION: On December 17, 2020, FERC confirmed and
approved Rate Schedules SLIP-F11 (SLCA/IP Firm Power), SP-NW5 (Network
Integration Transmission Service), SP-PTP9 (Firm Point-to-Point
Transmission Service), SP-NFT8 (Non-Firm Point-to-Point Transmission
Service), SP-UU2 (Unreserved Use Penalties), SP-EI5 (Energy and
Generator Imbalance Services), SP-SSR5 (Operating Reserves--Spinning
and Supplemental Reserve Services), and SP-SS1 (Sale of Surplus
Products) under Rate Order No. WAPA-190 (WAPA-190) on a final basis
through September 30, 2025.\1\
---------------------------------------------------------------------------
\1\ Order Confirming and Approving Rate Schedules on a Final
Basis, FERC Docket No. EF20-7-000, 173 FERC ] 61,230 (2020).
---------------------------------------------------------------------------
WAPA published a Federal Register notice (Proposed FRN) on June 28,
2021 (86 FR 34002), proposing modifications to only the firm power rate
schedule (SLIP-F11) established under WAPA-190. CRSP MC did not propose
any changes to the transmission and ancillary services rate schedules
established under WAPA-190, and they remain effective under WAPA-190
through September 30, 2025. The Proposed FRN also initiated a public
consultation and comment period and set forth the date and location of
the public information and public comment forums.
WAPA is implementing the firm power rate under Rate Schedule SLIP-
F12 to address worsening drought conditions in the southwestern United
States and volatile purchased power costs. The rates will go into
effect December 1, 2021, and remain in effect until December 31, 2023,
or until WAPA supersedes or changes the rates through another public
rate process pursuant to 10 CFR part 903, whichever occurs first. The
CRSP MC is only implementing the rate for 25 months to continue
collaborative conversations with customers and interested parties on
the most effective use of available generation and long-term strategies
for managing the cost of purchased power. CRSP MC is basing FY 2022 and
FY 2023 energy sales in the rate-setting Power Repayment Study (PRS) on
the Reclamation August 2021 24-month Study, and FY 2024 through FY 2026
sales on the CRSS traces and is forgoing purchased power in the rates.
Forgoing purchased power decreased the projected rate increase from 50
percent to 11 percent. CRSP MC will not be purchasing firming power to
meet Sustainable Hydropower (SHP) levels as it has in the past.
Calculated sales for the effective period of the rate will be limited
to forecasted generation, referred to as the Deliverable Sales Amount
(DSA). The DSA levels will be updated quarterly and provided to
customers for power scheduling and billing purposes. These quarterly
updates do not impact the rates. CRSP MC will firm to the DSA level if
necessary. For those customers who elect, CRSP MC will offer Western
Replacement Firming (WRF) purchased power to customers, as a pass-
through cost at market rates, to firm to SHP levels. Customers electing
not to take WRF will receive the DSA.
Legal Authority
By Delegation Order No. 00-037.00B, effective November 19, 2016,
the Secretary of Energy delegated: (1) The authority to develop power
and transmission rates to the WAPA Administrator; (2) the authority to
confirm, approve, and place such rates into effect on an interim basis
to the
[[Page 61212]]
Deputy Secretary of Energy; and (3) the authority to confirm, approve,
and place into effect on a final basis, or to remand or disapprove such
rates, to FERC. By Delegation Order No. S1-DEL-S4-2021, effective
February 25, 2021, the Acting Secretary of Energy also delegated the
authority to confirm, approve, and place such rates into effect on an
interim basis to the Under Secretary for Science (and Energy). By
Redelegation Order No. S4-DEL-OE1-2021, effective March 25, 2021, the
Acting Under Secretary for Science (and Energy) redelegated the
authority to confirm, approve, and place such rates into effect on an
interim basis to the Assistant Secretary for Electricity. By
Redelegation Order No. 00-002.10-05, effective July 8, 2020, the
Assistant Secretary for Electricity further redelegated the authority
to confirm, approve, and place such rates into effect on an interim
basis to WAPA's Administrator. This redelegation order, despite
predating the February 2021 and March 2021 delegations, remains valid.
This rate action is issued under Redelegation Order No. 00-002.10-05
and Department of Energy procedures for public participation in rate
adjustments set forth at 10 CFR part 903.\1\
---------------------------------------------------------------------------
\1\ 50 FR 37835 (Sept. 18, 1985) and 84 FR 5347 (Feb. 21, 2019).
---------------------------------------------------------------------------
Following review of CRSP MC's proposal, I hereby confirm, approve,
and place Rate Order No. WAPA-199, which provides the fixed rates for
firm power, into effect on an interim basis. WAPA will submit Rate
Order No. WAPA-199 to FERC for confirmation and approval on a final
basis.
Department of Energy
Administrator, Western Area Power Administration
In the Matter of:
Western Area Power Administration, Colorado River Storage Project
Management Center, Rate Adjustment for the Salt Lake City Area,
Integrated Projects Fixed Firm Power Rates
Rate Order No. WAPA-199
Order Confirming, Approving, and Placing the Salt Lake City Area
Integrated Projects Fixed Firm Power Rates Into Effect on an Interim
Basis
The fixed rates in Rate Order No. WAPA-199 are established
following section 302 of the Department of Energy (DOE) Organization
Act (42 U.S.C. 7152).\1\
---------------------------------------------------------------------------
\1\ This Act transferred to, and vested in, the Secretary of
Energy the power marketing functions of the Secretary of the
Department of the Interior and the Bureau of Reclamation
(Reclamation) under the Reclamation Act of 1902 (ch. 1093, 32 Stat.
388), as amended and supplemented by subsequent laws, particularly
section 9(c) of the Reclamation Project Act of 1939 (43 U.S.C.
485h(c)); and other acts that specifically apply to the project(s)
involved.
---------------------------------------------------------------------------
By Delegation Order No. 00-037.00B, effective November 19, 2016,
the Secretary of Energy delegated: (1) The authority to develop power
and transmission rates to the Western Area Power Administration's
(WAPA) Administrator; (2) the authority to confirm, approve, and place
such rates into effect on an interim basis to the Deputy Secretary of
Energy; and (3) the authority to confirm, approve on a final basis,
remand, or disapprove such rates to FERC. By Delegation Order No. S1-
DEL-S4-2021, effective February 25, 2021, the Acting Secretary of
Energy also delegated the authority to confirm, approve, and place such
rates into effect on an interim basis to the Under Secretary for
Science (and Energy). By Redelegation Order No. S4-DEL-OE1-2021,
effective March 25, 2021, the Acting Under Secretary for Science (and
Energy) redelegated the authority to confirm, approve, and place such
rates into effect on an interim basis to the Assistant Secretary for
Electricity. By Redelegation Order No. 00-002.10-05, effective July 8,
2020, the Assistant Secretary for Electricity further delegated the
authority to confirm, approve, and place such rates into effect on an
interim basis to WAPA's Administrator. This redelegation order, despite
predating the February 2021 and March 2021 delegations remains valid.
This rate action is issued under Redelegation Order No. 00-002.10-05
and DOE procedures for public participation in rate adjustments set
forth at 10 CFR part 903.\1\
---------------------------------------------------------------------------
\1\ 50 FR 37835 (Sept. 18, 1985) and 84 FR 5347 (Feb. 21, 2019).
---------------------------------------------------------------------------
Acronyms, Terms, and Definitions
As used in this Rate Order No. WAPA-199, the following acronyms,
terms, and definitions apply:
Basin Fund: Upper Colorado River Basin Fund.
Capacity: The electric capability of a generator, transformer,
transmission circuit, or other equipment. It is expressed in kilowatts
(kW) or megawatts (MW).
Capacity Rate: The rate which sets forth the charges for capacity.
It is expressed in dollars per kilowatt-month and applied to each
kilowatt delivered to each Customer.
CDP: Customer Displacement Power.
Composite Rate: The Power Repayment Study (PRS) rate for commercial
firm power, which is the total annual revenue requirement for capacity
and energy divided by the total annual energy sales. It is expressed in
mills per kilowatt-hour and used only for comparison purposes.
CRC: Cost Recovery Charge.
CROD: Contract Rate of Delivery. The maximum amount of capacity
made available to a preference Customer for a period specified under a
contract.
Customer: Firm electric service customer(s) contractually receiving
SLCA/IP power and energy.
CY: Calendar Year. When used in the CRC it is the 12-month period
the CRC is in effect.
DSA: Deliverable Sales Amount--marketable generation level, above
which WAPA will forgo purchased power.
Energy Rate: The rate which sets forth the charges for energy. It
is expressed in mills/kWh and applied to each DSA kWh delivered to each
Customer.
Firm: A type of product or service available at the time requested
by the Customer.
FY: Fiscal Year, October 1 to September 30.
GWh: Gigawatt-hour--the electrical unit of energy that equals 1
billion watthours or 1 million kWh.
Integrated Projects: The resources and revenue requirements of the
Collbran, Dolores, Rio Grande, and Seedskadee projects blended with the
CRSP to create the SLCA/IP resources and rate.
kW: Kilowatt--the electrical unit of capacity that equals 1,000
watts.
kWh: Kilowatt-hour--the electrical unit of energy that equals 1,000
watts in 1 hour.
kWmonth: Kilowatt-month--the electrical unit of the monthly amount
of capacity.
MAF: Million Acre-Feet. The amount of gallons of water required to
cover 1 million acres, 1 foot in depth.
Mill: A monetary denomination of the United States that equals one
tenth of a cent or one thousandth of a dollar.
Mills/kWh: Mills per kilowatt-hour--the unit of charge for energy.
MW: Megawatt--the electrical unit of capacity that equals 1 million
watts or 1,000 kilowatts.
MWh: One million watt-hours of electric energy. A unit of
electrical energy which equals 1 megawatt of power used for 1 hour.
NEPA: National Environmental Policy Act of 1969, as amended.
OASIS: Open Access Same-Time Information System--An electronic
posting system that a service provider maintains for transmission
access data that allows all Customers to view information
simultaneously.
O&M: Operations and Maintenance.
OM&R: Operations, Maintenance and Replacements.
[[Page 61213]]
Power: Capacity and energy.
Project Use: Power used to operate SLCA/IP and CRSP facilities
under Reclamation Law.
Provisional Rate: A rate confirmed, approved, and placed into
effect on an interim basis by the Secretary or his/her designee.
Rate Brochure: A document prepared for public distribution
explaining the rationale and background for the information contained
in this rate order.
Ratesetting PRS: The Power Repayment Study (PRS) used for the rate
adjustment period.
Revenue Requirement: The revenue required to recover O&M expenses,
purchased power and transmission service expenses, interest, deferred
expenses, and repayment of Federal investments, or other assigned
costs.
SHP: Sustainable Hydropower (long-term SLCA/IP hydro capacity with
energy).
SLCA/IP: Salt Lake City Area Integrated Projects.
WL: Waiver Level.
Work Plan: An estimate of costs that are expected to become the
Congressional Budget for WAPA and Reclamation. Also known as a Work
Program.
WRF: Western Replacement Firming.
WRP: Western Replacement Power.
Effective Date
The Provisional Rate Schedule SLIP-F12 will take effect on the
first day of the first full billing period beginning on or after
December 1, 2021, and will remain in effect through December 31, 2023,
pending approval by FERC on a final basis or until superseded.
Public Notice and Comment
The CRSP MC followed the Procedures for Public Participation in
Power and Transmission Rate Adjustments and Extensions, 10 CFR part
903, in developing these fixed rates. Following are the steps CRSP MC
took to involve interested parties in the rate process:
1. On June 28, 2021, a Federal Register notice (86 FR 34002)
(Proposal FRN) announced the proposed rates and launched the 65-day
public consultation and comment period. The comment period was reduced
from the customary 90-day period due to the $20 million financial
impact of not implementing the rate by December 1, 2021.
2. On June 28, 2021, CRSP MC notified Customers and interested
parties of the proposed rates and provided a copy of the published
Proposal FRN.
3. On July 7, 2021, CRSP MC held a virtual public information
forum. CRSP MC representatives explained the proposed fixed rates,
answered questions, and gave notice that more information was available
in the Rate Brochure.
4. On July 28, 2021, CRSP MC held a virtual public information
forum on purchased power and WRF. CRSP MC representatives explained the
process used to project purchase power, how WRF will be implemented,
answered questions, and gave notice that more information would be
available in a subsequent version of the Rate Brochure and provided
points of contact for additional questions on WRF implementation.
5. On July 29, 2021, CRSP MC held a virtual public information
forum on the CRC. CRSP MC representatives explained the purpose of the
CRC, the need for changes, how it is calculated and implemented,
answered questions, and gave notice that more information was available
in the Rate Brochure.
6. On August 11, 2021, CRSP MC held a virtual public comment forum.
This provided Customers and other interested parties an opportunity to
provide official comments for the record.
7. On August 13, 2021, CRSP MC posted responses to questions asked
during the August 11, 2021, virtual public comment forum on the rate
action website and notified the Customers and interested parties via
email.
8. CRSP MC provided a website that contains all dates, Customer
letters, presentations, FRNs, Rate Brochure, and other information
about this rate process. The rate action website is located at
www.wapa.gov/regions/CRSP/rates/Pages/rate-order-199.aspx.
9. During the 65-day consultation and comment period, which ended
on August 31, 2021, CRSP MC received 10 oral comments at the August 11,
2021, virtual public comment forum, and seven comment letters. All
comments from the virtual public comment forum were addressed by WAPA
via email and/or responses were posted to the rate action website on
August 13, 2021. The comments and CRSP MC responses are addressed in
the Comments section and have been considered in the preparation of
this Rate Order No. WAPA-199.
Oral comments were received from the following organizations:
Colorado River Energy Distributors Association (CREDA)
Utah Associated Municipal Power Systems (UAMPS)
Arizona Electric Power Cooperative (AEPCO)
Written comments were received from the following organizations:
Colorado River Energy Distributors Association (CREDA)
Arizona Electric Power Cooperative (AEPCO)
Municipal Energy Agency of Nebraska (MEAN/NMPP)
Platte River Power Authority (PRPA)
Tri-State Generation and Transmission Association, Inc. (TRI-STATE)
Utah Rural Electric Cooperative Association (URECA)
Utah Municipal Power Agency (UMPA)
10. CRSP MC received comments on the original Rate Brochure.
Comments were addressed in subsequent versions of the Rate Brochure.
11. CRSP MC provided a second consultation and comment period from
September 22 through October 6, 2021. This comment period facilitated
Customer feedback in reference to purchased power and generation
updates. The comments and CRSP MC responses are addressed in the
Comments section, and all comments have been considered in the
preparation of this Rate Order No. WAPA-199.
Written comments were received from the following organizations:
Colorado River Energy Distributors Association (CREDA)
Platte River Power Authority (PRPA)
Power Repayment Study--Firm Power Service Rate Discussion
CRSP MC prepares PRSs each FY to determine if revenues will be
sufficient to repay, within the required time, all costs assigned to
the SLCA/IP. Repayment criteria are based on applicable laws and
legislation, as well as policies including DOE Order RA 6120.2. To meet
the cost recovery criteria outlined in DOE Order RA 6120.2, a revised
PRS and rate adjustment have been developed to demonstrate that
sufficient revenues will be collected under the Provisional Rate to
meet future obligations. The revenue requirement and composite rate for
SLCA/IP firm power service are being increased, as indicated in Table
1:
[[Page 61214]]
Table 1--Comparison of Revenue Requirements and Composite Rates
----------------------------------------------------------------------------------------------------------------
Provisional
Firm power service Existing requirements requirements (December Percent change
(October 1, 2020) 1, 2021)
----------------------------------------------------------------------------------------------------------------
Revenue Requirement (million $)............... $173.511 $181,197 +4.4
Composite Rate (mills/kWh).................... 27.45 30.51 +11.1
----------------------------------------------------------------------------------------------------------------
Under the existing rate methodology, rates for firm power service
are designed to recover an annual revenue requirement that includes
power investment repayment, aid to irrigation repayment, interest, O&M,
replacements, and other expenses within the allowable period.
Firm Power Service--Existing and Provisional Rates
CRSP MC is implementing this rate action primarily in response to a
large increase in purchased power costs due to worsening drought
conditions in the southwestern United States and an increase to OM&R
expenses.
CRSP MC is basing sales in the rate on forecasted generation in
Reclamation's August 2021 24-month Study for the effective period of
the rate and is subsequently forgoing purchased power in the
Ratesetting PRS. Forgoing purchased power mitigates the projected rate
increase from 50-percent down to 11-percent. CRSP MC will not
automatically purchase firming power to SHP levels. For those Customers
who elect, CRSP MC will purchase WRF power as a pass-through cost, at
market rates, up to SHP levels. CRSP MC will purchase power to firm to
the forecasted generation level, referred to as the DSA. The DSA will
be updated quarterly as shown in Table 2. Customers will have at least
14 days to affirmatively select WRF for each quarter. Quarterly notices
provide flexibility in responding to changes in hydrology and will not
impact the rates. Customers can elect the full quarter or specific
months within the quarter.
Table 2--Quarterly DSA Adjustment Schedule
------------------------------------------------------------------------
Reclamation 24- Notify customers
Quarter impacted month study by:
------------------------------------------------------------------------
December 2021................... August 2021....... mid-October 2021.
January-March 2022.............. November 2021..... Est: November 20,
2021.
April-June 2022................. February 2022..... Est: February 20,
2022.
July-September 2022............. May 2022.......... Est: May 20, 2022.
October-December 2022........... August 2022....... Est: August 20,
2022.
January-March 2023.............. November 2022..... Est: November 20,
2022.
April-June 2023................. February 2023..... Est: February 20,
2023.
July-September 2023............. May 2023.......... Est: May 20, 2023.
October-December 2023........... August 2023....... Est: August 20,
2023.
------------------------------------------------------------------------
CRSP MC provided information on the implementation process of the
WRF and DSA in the Rate Brochure, at the virtual public information
forum, at a virtual purchased power forum, and replied to questions
from the virtual public comment forum via email. This information was
published on the rate action website at: www.wapa.gov/regions/CRSP/rates/Pages/rates.aspx.
A comparison of the existing and provisional rates for firm power
service is listed in Table 3. The Provisional Rate is a fixed rate that
will go into effect December 1, 2021, and remain in effect through
December 31, 2023, or until WAPA supersedes or changes the rates
through another public rate process pursuant to 10 CFR part 903,
whichever occurs first.
Table 3--Comparison of Existing and Provisional Rate
----------------------------------------------------------------------------------------------------------------
Existing charges Provisional
under rate charges under rate
Firm power service schedule SLIP-F11 schedule SLIP-F12 Percent change
as of October 1, as of December 1,
2020 2021
----------------------------------------------------------------------------------------------------------------
Firm Energy Rate (mills/kWh)........................ 11.43 12.36 +8.1
Firm Capacity Rate ($/kWmonth)...................... 4.85 5.25 +8.3
----------------------------------------------------------------------------------------------------------------
Statement of Revenue and Related Expenses
Table 4 provides a comparison of the average annual expense data
for the firm power service revenue requirement through the rate-setting
period. The purchase power shown in the table reflects purchase power
costs for October and November 2021 that fall under the SLIP F11 rates.
There is no projected purchase power amount included in the rate for
service from December 2021 through December 2026.
Table 4--Annual Revenue Requirements and Firm Power Rates Comparison Table
----------------------------------------------------------------------------------------------------------------
Existing rate Provisional rate Difference
($000) ($000) ($000)
----------------------------------------------------------------------------------------------------------------
Rate Setting Period....................................... 2021-2038 2022-2045
----------------------------------------------------------------------------------------------------------------
[[Page 61215]]
Revenue Distribution:
Expenses:
O&M............................................... $97,352 $103,095 $5,743
Purchase Power.................................... 1,119 833 (286)
Transmission...................................... 8,998 8,984 (14)
Integrated Projects requirements.................. 6,485 7,043 558
Interest.......................................... 6,066 6,207 141
Other............................................. 17,909 13,547 (4,362)
-----------------------------------------------------
Total Expenses................................ 137,928 139,709 1,781
-----------------------------------------------------
Principal Payments:
Capitalized Expenses (deficits)................... 0 838 838
Replacements...................................... 26,918 29,581 2,663
Original Project and Additions.................... 2,484 1,846 (638)
Irrigation........................................ 6,181 9,223 3,042
-----------------------------------------------------
Total Principal Payments...................... 35,583 41,488 5,905
-----------------------------------------------------
Annual Revenue Requirement.................... 173,511 181,197 7,686
----------------------------------------------------------------------------------------------------------------
The rates would provide sufficient revenue to recover annual O&M
expenses, replacement expenses, interest expense, irrigation
assistance, and capital repayment requirements within the cost recovery
criteria set forth in Department of Energy (DOE) Order No. RA 6120.2.
Purchased power required to supplement hydropower deliveries up to
contractual levels will be passed through to Customers under a separate
charge, WRF, which would be in addition to the rate for hydropower
deliveries. Any Customer not receiving WRF will not be charged the
purchased power charge and would receive its proportionate amount of
the DSA capacity and energy from WAPA each month.
SLCA/IP Firm Power Rate
The revenue requirement for Rate Schedule SLIP-F12 is based on
current data available, specifically the FY 2020 historical financial
data, FY 2022 Work Plan for WAPA, FY 2023 Work Plan for Reclamation,
and Reclamation's August 2021 24-Month Study (24-month Study) and
Colorado River Simulation System (CRSS) traces.
Under rate schedule SLIP-F12, WAPA will use the Reclamation August
2021 24-Month Study to determine generation and projected sales for the
2 rate years (FYs 22-23) and CRSS for FYs 24-26 of the rate-setting
period. Additionally, the rate schedule includes actions WAPA will take
should Lake Powell's water level drop below the level at which power
can be generated.
Cost Recovery Charge
WAPA will retain the CRC as a mechanism to use, if necessary, to
adequately recover and maintain a sufficient balance in the Basin Fund
in the event projected expenses significantly exceed projected revenue
estimates. The Basin Fund is a revolving fund that operates using CRSP
MC power revenues without annual appropriations. The CRC is an
additional surcharge on all long-term energy sales provided under the
WAPA SLCA/IP firm electric service contracts. The CRC may be
implemented when, among other things, the Basin Fund cash balance is at
risk due to low hydropower generation, high prices for firming power,
or emergency capitalized investment funding. The CRC is independent of
the SLCA/IP PRS calculations.
WAPA reserves the right to implement a CRC at any point throughout
the year using guidance from the existing implementation criteria in
Table 5 and the latest 24-month Study from Reclamation. An established
CRC would be in effect for 12 months from the date implemented. If
circumstances dictate the need to reassess an established CRC, the
updated CRC will supersede the previous CRC and remain in effect for 12
months. The CRC is implemented at WAPA's discretion based on the
balance of the Basin Fund and WAPA's ability to meet contractual
requirements. The minimum Basin Fund carryover balance is $40 million.
Table 5--CRC Implementation Tiers
----------------------------------------------------------------------------------------------------------------
Criteria, if the basin fund beginning balance
Tier is: Notification
----------------------------------------------------------------------------------------------------------------
i................... Greater than $150 million with an expected Annually (July).
decrease to below $75 million.
ii.................. Less than $150 million but greater than $120
million with an expected 50-percent decrease
in the next CY.
iii................. Less than $120 million but greater than $90
million with an expected 40-percent decrease
in the next CY.
iv.................. Less than $90 million but greater than $60 Semi-Annual (July/January).
million with an expected 25-percent decrease
in the next CY.
v................... Less than $60 million but greater than $40 Monthly.
million with an expected decrease to below
$40 million in the next CY.
----------------------------------------------------------------------------------------------------------------
[[Page 61216]]
WAPA reserves the right to implement a CRC throughout the year if
annual water releases from Glen Canyon Dam fall below 8.23 MAF,
regardless of the Basin Fund balance.
If a CRC is implemented, CRSP MC will establish an energy Waiver
Level (WL) using the CRC formula. Customers could accept either the CRC
or WL. The WL provides WAPA the ability to reduce purchase power
expenses by delivering less energy than its contractual obligations.
For those Customers who agree to schedule no more energy than their
proportionate share of the WL, WAPA would waive the CRC for that year.
If, in any month, the annual water release volumes from Glen Canyon
Dam return to 8.23 MAF or higher while a CRC is in place, a new CRC
will be calculated for the next month, and each Customer will be
notified of the recalculated CRC results.
CRC sample calculations, narratives, and schedules are located on
the CRC web page: www.wapa.gov/regions/CRSP/rates/Pages/cost-recovery-charge.aspx.
Comments
CRSP MC received 52 oral or written comments during the public
consultation and comment period. The comments expressed have been
paraphrased or consolidated, where appropriate, without compromising
the meaning of the comments.
Comments on Firm Power Rates
A. Comment: Commentor urged WAPA to continue to refine elements
other than purchased power in the PRS to result in the lowest possible
rate, consistent with sound business principles.
Response: CRSP MC analyzed data including O&M work plans, 10-year
plans for capital investment, and Customer agreements, as well as
Customer input, to ensure rates are the lowest possible consistent with
sound business principles.
B. Comment: Commentor requested that WAPA continue to reflect
``expense reductions to the work plans as they become available,''
until the latest possible date, as those work plan-related discussions
are still underway.
Response: CRSP MC incorporated changes to the Reclamation and WAPA
work plan reviews into the power repayment study as the information was
made available including using WAPA's FY 22 Work Plan instead of the FY
23 Work Plan. CRSP MC updated supporting data documents and posted them
to the rate action website and included the results in the Rate
Brochure updates.
C. Comment: Multiple commentors asked about the availability of
firm transmission for Customers who do not elect WRF and what CRSP MC
will do with surplus transmission.
Response: The CROD capacity will not be reduced. Available capacity
up to the CROD is available for Customer use as WRP and CDP as provided
in the Customers' SLCA/IP firm electric service contracts. Surplus
transmission, if any, would be made available through the OASIS based
on existing policy and procedures.
D. Comment: Commentor expressed concerns over ``rate shock'' for
small Customers and stated the rate process provides very little time
for Customers to design and implement retail rate adjustments that
account for these changes. Commentor believes WAPA must consider this
rate shock and what (if any) new value WAPA can provide to help offset
this significant increase.
Response: CRSP MC understands that increasing rates impacts its
Customers. CRSP MC operates on a cost-basis and must establish rates to
collect sufficient revenue to meet operational expense and repayment
obligations. Significant increases in purchase power costs warrant the
need for the rate action. CRSP MC followed public notice requirements
of the Administrative Procedure Act in setting forth this proposed rate
change. CRSP MC implemented this short rate period so collaborative
conversations with interested parties could occur over the next 2 years
on the most effective use of available generation and long-term
strategies for managing the cost of purchased power.
Comments on Services
A. Comment: Commentor believes WAPA's Customers must have the
ability to convert some of their allocation into ancillary services to
offset the financial impacts of the rate increase.
Response: All available energy is committed to firm power service
deliveries.
B. Comment: One commentor asked WAPA to clarify whether the firm
capacity and energy will be restored to Customers in the event the
Colorado River Basin's hydrological conditions revert to historical
levels.
Response: Should forecasted hydrological conditions improve, the
DSA levels will rise providing additional energy allocations for
Customers. AHP as defined in the SLCA/IP firm electric service contract
will also be offered if hydrological conditions improve significantly
within an established quarter.
C. Comment: One commentor does not agree with WAPA's position that
the ``Tribe under the benefit crediting contract would need to decide
whether to receive WRF and communicate that decision to its benefit
crediting utility.'' Commentor's position is the election of WRF should
be that of the benefit crediting utility, not the Tribe.
Response: CRSP MC has clarified this issue. WRF may be selected by
the utility providing the benefit crediting service. This is like the
existing treatment under the WRP program. The benefit crediting amount
provided to a Tribe is to be calculated on the Tribe's hydropower
delivery amounts.
D. Comment: Commentor asked that WAPA ensure participants retain
the option to independently purchase replacement power to cover
shortfalls in CRSP production. The proposed opt-in process should be,
at most, seasonal (every 6 months) to prevent adverse selection issues
or last-minute decisions by individual members that change market
conditions for all project participants.
Response: Customers can independently use their own resources or
purchase their own firming power under the CDP program. To provide
greater flexibility in responding to hydrology, CRSP MC has enhanced
the DSA and WRF programs by using quarterly notices to the Customers.
Although 6-month periods were originally proposed, Customers requested
additional flexibility in determining which months to potentially
purchase WRF. Quarterly notices will provide Customers additional
flexibility in meeting their resource needs and provide CRSP MC more
certainty about water releases and hydropower generation availability.
E. Comment: Commentor asked that WAPA protect preference Customers'
firm transmission rights, so Customers can use their transmission
rights for power delivered to make up for power WAPA cannot provide.
Commentor asked that WAPA maintain the current practice for firm
transmission for power delivered in lieu of WAPA power, which was
implemented earlier in this ongoing drought.
Response: Available capacity up to the CROD is still available for
Customer use as WRP and CDP.
Comments in Support
A. Comment: Multiple commentors provided favorable comments
thanking WAPA for its willingness to collaborate through rate,
resource, and work plan processes; inclusion of two topical
[[Page 61217]]
virtual public forums to assist in Customer review and understanding of
the WAPA-199 rate; appreciation for WAPA's Customer notification of
materials being posted on the rate website; appreciation for WAPA's
willingness to work with them to improve the capability and
accessibility of the modeling tools used to analyze and produce CRSP
rate scenarios in a timely manner; appreciation for WAPA's flexibility
in providing a 14-day consultation and comment period after ``final
purchased power amounts'' have been posted to its website; appreciation
towards WAPA, CRSP staff, and Reclamation's work with Customers during
this rate process and through the process referred to as the ``work
program review'' process.
Response: CRSP MC appreciates the feedback and recognizes the
benefits of collaborating with Customers and interested parties.
B. Comment: Two commentors expressed appreciation for CRSP MC's and
Upper Colorado Region of Reclamation's approach to mitigating drought
impacts and ensuring that the Basin Fund remains viable through the new
rate components and continuation of the WRP and CDP processes, as well
as the PRS and rates.
Response: CRSP MC appreciates the feedback.
C. Comment: Commentor expressed support for the revisions made to
the CRC described in the Rate Brochure.
Response: CRSP MC appreciates the feedback on the CRC revisions.
Comments on Customer Communications
A. Comment: Two commentors requested WAPA continue timely
communication, collaboration, and transparency with CRSP Customers on
decisions, ongoing concerns, and potential impacts of recent Senate
infrastructure funding.
Response: While the Senate infrastructure funding is out of scope
for this rate action, CRSP MC understands the benefits of
communication, collaboration, and transparency with its Customers in
addressing potential rate impacts.
B. Comment: One commentor requested WAPA incorporate information/
adjustments from pending Reclamation and WAPA reviews into the final
proposed/provisional rate, and the results of that inclusion be
provided to them.
Response: CRSP MC incorporated changes tied to the Reclamation and
WAPA work plan reviews into the PRS as the information was made
available. CRSP MC updated supporting data documents, posted them to
the rate action website, and included the results in the Rate Brochure
updates.
C. Comment: One commentor requested WAPA ensure Customers are
notified of the Provisional Rate under this rate order prior to the
issuance of Customer Notification of the DSA Season Update for Winter
2022 Season.
Response: CRSP MC provided the projected final rate on September
22, 2021, when it opened the Customer Comment Period on Purchased Power
and Generation. The rate was subsequently decreased based on changes to
project use power and CRSP MC's decision to use the FY 2022 work plan
for the rate-setting period to reduce costs.
D. Comment: Commenter requested their most recent correspondence be
included in the WAPA-199 record.
Response: CRSP MC filed all received comments in the decision of
record for this rate process.
E. Comment: One commentor asked WAPA to continue its practice of
collaboration and transparency for future decisions that affect CRSP
Customers, such as costs for shaping and firming services as additional
power is needed to maintain reliable supply.
Response: CRSP MC will continue its practice of collaboration and
transparency.
Comments on Other
A. Comment: Commentor expressed recognition of the significance of
the current drought conditions in the Colorado River Basin and the
challenges that are being presented to WAPA and the CRSP Customers.
Response: CRSP MC appreciates the feedback.
B. Comment: One commentor expressed appreciation that the current
scope of this rate order does not propose changes to ancillary
services. Commentor wants any future changes to ancillary services to
be part of a separate rulemaking.
Response: The current transmission and ancillary service formula
rates established under Rate Order WAPA-190 required no modifications
and continue to be effective under Rate Order WAPA-190 through
September 30, 2025.
Second Comment Period Comments
A. Comment: Commenters expressed that it does not make sense to
apply the CRC to all SHP and DSA because DSA is a subset of SHP.
Response: CRSP MC concurs. Since CRSP MC is only purchasing firming
power to the DSA level, instances of SHP in the CRC will be replaced
with DSA in the FRN and supporting documentation.
B. Comment: Commenters expressed that the CRC does not belong in
the WRF cost recovery equation.
Response: CRSP MC concurs that WRF is exempt from the CRC
calculation. The CRC only applies to the firming purchases up to the
DSA level.
C. Comment: Commenter said, ``Because any portion of a customer's
SHP above DSA will necessarily be WRF, the CRC should not apply to the
above-DSA amount.''
Response: CRSP MC concurs that the CRC only applies to firming
purchases up to the DSA level and made conforming changes within the
FRN and supporting documentation.
D. Comment: Commenter thanks WAPA for the additional comment period
to respond to updated elements of its CRSP rate proposal, and for its
continuing commitment to transparency and collaboration in the rate-
setting process.
Response: WAPA appreciates the feedback.
E. Comment: Commenter supports WAPA making ``additional changes to
the work plan'' . . . and including them in the final rate package
without ``an additional comment period for Customer review.''
Response: The WAPA decision not to initiate an additional comment
period was due to the changes decreasing the proposed rate. Had the
recent update to the workplan increased the proposed rate, WAPA would
have considered an additional comment period or delayed implementation
of the change until the next rate action.
F. Comment: Commenter supports the change in the DSA and WRF to
quarterly time frames, and the addition that Customers may elect
specific months within the quarter, to receive WRF.
Response: CRSP MC appreciates the feedback.
G. Comment: Commenter urges ongoing customer collaboration to
address hydrologic conditions and forecasts, Basin Fund targets
(including any methodology changes which may be made), MOA transfer
timing, non-power program and non-reimbursable funding and
Congressional action.
Response: CRSP MC recognizes the benefits of customer collaboration
in dealing with the drought and impacts on generation and the energy
rates. CRSP MC will continue its practice of transparency by providing
information as it becomes available.
H. Comment: Commenter supports the collaborative effort WAPA has
made
[[Page 61218]]
with Customers to develop long-term solutions to manage revenue
requirements and cash flow.
Response: WAPA appreciates the feedback and recognizes the benefits
of customer collaboration.
Certification of Rates
I have certified that the Provisional Rates for SLCA/IP Firm Power
under Rate Schedule SLIP-F12 are the lowest possible rates, consistent
with sound business principles. The Provisional Rates were developed
following administrative policies and applicable laws.
Availability of Information
Information about this rate adjustment, including the Rate
Brochure, PRSs, comments, letters, memoranda, and other supporting
materials that were used to develop the Provisional Rates, is available
for inspection and copying at the Colorado River Storage Project
Management Center Office, 1800 South Rio Grande Avenue, Montrose, CO.
Many of these documents are also available on WAPA's website at
www.wapa.gov/regions/CRSP/rates/Pages/rates.aspx, or email; [email protected].
Ratemaking Procedure Requirements
Environmental Compliance
WAPA has determined this action fits within the following
categorical exclusions listed in appendix B to subpart D of 10 CFR part
1021.410: B4.3 (Electric power marketing rate changes) and B4.4 (Power
marketing services and activities). Categorically excluded projects and
activities do not require preparation of either an environmental impact
statement or an environmental assessment.\1\ Specifically, WAPA has
determined that this rulemaking is consistent with activities
identified in B4, Categorical Exclusions Applicable to Specific Agency
Actions (see 10 CFR part 1021, appendix B to subpart D, part B4). A
copy of the categorical exclusion determination is available on WAPA's
website at: www.wapa.gov/regions/CRSP/environment/Pages/environment.aspx.
---------------------------------------------------------------------------
\1\ The determination was done in compliance with NEPA (42
U.S.C. 4321-4347); the Council on Environmental Quality Regulations
for implementing NEPA (40 CFR parts 1500-1508); and DOE NEPA
Implementing Procedures and Guidelines (10 CFR part 1021).
---------------------------------------------------------------------------
Determination Under Executive Order 12866
WAPA has an exemption from centralized regulatory review under
Executive Order 12866; accordingly, no clearance of this notice by the
Office of Management and Budget is required.
Submission to the Federal Energy Regulatory Commission
The Provisional Rate herein confirmed, approved, and placed into
effect on an interim basis, together with supporting documents, will be
submitted to FERC for confirmation and final approval.
Order
In view of the above, and under the authority delegated to me, I
hereby confirm, approve, and place into effect, on an interim basis,
Rate Order No. WAPA-199. The rates will remain in effect on an interim
basis until: (1) FERC confirms and approves them on a final basis; (2)
subsequent rates are confirmed and approved; or (3) such rates are
superseded.
Signing Authority
This document of the Department of Energy was signed on October 28,
2021, by Tracey LeBeau, Administrator, Western Area Power
Administration, pursuant to delegated authority from the Secretary of
Energy. That document, with the original signature and date, is
maintained by DOE. For administrative purposes only, and in compliance
with requirements of the Office of the Federal Register, the
undersigned DOE Federal Register Liaison Officer has been authorized to
sign and submit the document in electronic format for publication, as
an official document of the Department of Energy. This administrative
process in no way alters the legal effect of this document upon
publication in the Federal Register.
Signed in Washington, DC, on November 2, 2021.
Treena V. Garrett
Federal Register Liaison Officer, U.S. Department of Energy.
Rate Schedule SLIP-F12
(Supersedes Rate Schedule SLIP-F11)
United States Department of Energy
Western Area Power Administration
Colorado River Storage Project Management Center Salt Lake City Area
Integrated Projects
Schedule of Rates for Firm Power Service (Approved Under Rate Order No.
WAPA-199)
Effective: The first day of the first full billing period beginning
on or after December 1, 2021, and extending through December 31, 2023,
or until superseded by another rate schedule, whichever occurs earlier.
Available: In the area served by the Salt Lake City Area Integrated
Projects.
Applicable: To the wholesale power Customer for firm power service
supplied through one meter at one point of delivery or as otherwise
established by contract.
Character: Alternating current, 60 hertz, three-phase, delivered
and metered at the voltages and points established by contract.
Monthly Rate: Demand Charge: $5.25 per kilowatt of billing demand.
Energy Charge: $12.36 mills per kilowatthour of use of Deliverable
Sales Amount (DSA) energy.
Modification of Purchased Power: WAPA will not automatically
provide purchased power to firm to SHP energy allocations, nor will
there be any purchased power costs under Rate Order WAPA-199 in the
rate setting period in the power repayment study under Rate Order WAPA-
199. WAPA will establish the rates using the projected DSA data in the
Bureau of Reclamation's (Reclamation) August 2021 24-month Study and
Reclamation's August 2021 Colorado River Simulation System traces.
Western Replacement Firming (WRF): WRF applies to pass-through
purchased power costs for energy provided between the DSA level and SHP
energy allocation. WRF is an optional product. Customers must elect
quarterly, and may elect specific months within the quarter, to receive
WRF. The charge for this purchased power will be determined at the time
of the purchase based on market rates. There are no losses or an
administrative fee charged to WRF. A schedule for the quarterly updates
is in the rate brochure on the rate action website: www.wapa.gov/regions/CRSP/rates/Pages/rates.aspx.
Billing Demand: The billing demand will be the greater of:
1. The highest 30-minute integrated demand measured during the
month up to, but not more than, the delivery obligation under the power
sales contract, or,
2. The Contract Rate of Delivery.
Billing Energy: The billing energy will be the energy measured
during the month up to, but not more than, the delivery obligation
under the power sales contract.
Adjustment for Transformer Losses: If delivery is made at
transmission voltage but metered on the low-voltage side of the
substation, the meter readings will be increased to compensate for
transformer losses as provided in the contract.
Adjustment for Power Factor: The Customer will be required to
maintain a power factor at all points of
[[Page 61219]]
measurement between 95 percent lagging and 95 percent leading.
Adjustment for Western Replacement Power (WRP): Pursuant to the
Customer's Firm Electric Service Contract, as amended, WAPA will bill
the Customer for its proportionate share of the costs of WRP within a
given time. WAPA will include in the monthly power bill the cost of the
WRP, and the incremental administrative costs associated with WRP.
Adjustment for Customer Displacement Power (CDP) Administrative
Charges: WAPA will include in the Customer's regular monthly power bill
the incremental administrative costs associated with CDP.
Adjustment for Minimum Power Pool: If Lake Powell drops below
``minimum power pool'' and power cannot be generated, WAPA will provide
30 days' notice to the Customers prior to reducing the DSA.
Cost Recovery Charge (CRC): To adequately recover and maintain a
sufficient balance in the Basin Fund, WAPA uses a cost recovery
mechanism, called a CRC. The CRC is a charge on all long-term energy
sales provided under WAPA's SLCA/IP firm electric service contracts.
This charge will be, at a minimum, recalculated before July 1 of
each year, and WAPA will provide notification to the Customers
consistent with the procedures in 10 CFR 903. WAPA has the discretion
to implement the CRC at any point throughout the year using the
criteria in Table 1. The charge, if needed, will be placed into effect
on the first day of the first full-billing period beginning on or after
the first day of the month the CRC is implemented. For the purposes of
the CRC, the 12-month period of a CRC will be described as a calendar
year (CY). The CRC will be calculated as follows:
Table 1--CRC Tiers
----------------------------------------------------------------------------------------------------------------
Criteria, if the basin fund beginning balance
Tier (BFBB) is: Notification
----------------------------------------------------------------------------------------------------------------
i.................................... Greater than $150 million, with an expected Annually (July).
decrease to below $75 million.
ii................................... Less than $150 million but greater than $120
million, with an expected 50 percent decrease
in the next CY.
iii.................................. Less than $120 million but greater than $90
million, with an expected 40 percent decrease
in the next CY.
iv................................... Less than $90 million but greater than $60 Semi-Annual (July/
million, with an expected 25 percent decrease January).
in the next CY.
v.................................... Less than $60 million but greater than $40 Monthly.
million with an expected decrease to below $40
million in the next CY.
----------------------------------------------------------------------------------------------------------------
CRC sample calculations, narratives, and schedules showing the
dates for implementing a CRC throughout the year are located at the CRC
web page: www.wapa.gov/regions/CRSP/rates/Pages/cost-recovery-charge.aspx.
Waiver Level (WL)
WAPA will establish a WL that provides WAPA the ability to reduce
purchased power expenses by scheduling less energy than what is
contractually required. Therefore, for those Customers who voluntarily
schedule no more energy than their proportionate share of the WL, WAPA
will waive the CRC for that year. After the Funds Available have been
determined, the WL will be set at the sum of the energy that can be
provided through hydro generation and purchased with Funds Available.
The WL will not be less than the forecasted Hydro Energy.
Trigger for Water Release Criteria: In the event that Reclamation's
24-month study projects Glen Canyon Dam water releases will drop below
8.23 million acre feet (MAF) in a water year (October through
September), WAPA will recalculate the CRC to include those lower
estimates of hydropower generation. WAPA, as in the yearly projection
for the CRC, will give the Customers a 45-day notice to request a
waiver of the CRC if they do not want to have the CRC charge added to
their energy bills. This recalculation will remain in effect for the
remainder of the CY.
If the annual water release volumes from Glen Canyon Dam return to
8.23 MAF or higher during the trigger implementation, a new CRC will be
calculated for the next month, and the Customer will be notified.
Trigger for New Rate Criteria
WAPA would reassess an implemented CRC when a new rate goes into
effect to determine if the implemented CRC should be continued,
superseded, or terminated.
Prior Year Adjustment for CRC: Since the annual determination of
the CRC is based upon estimates, an annual, prior-year adjustment (PYA)
will be calculated for those who did not elect the waiver level. The
PYA will be based on the 12-month period the CRC was in effect.
The Customers' PYA will be based on their prior 12-months' energy
multiplied by the PYA mills/kWh to determine the dollar value that will
be assessed. The Customer will be charged or credited for this dollar
amount equally in the remaining months of the next 12-month billing
cycle. WAPA will complete this calculation within 2 months of the end
of the CRC. Therefore, if the PYA is calculated in June, the charge/
credit will be spread over the remaining 9 months of the CY (July
through March).
Adjustment for CRC Waiver: Customers can choose not to take the
full DSA energy supplied as determined in the attached formulas for CRC
and will be billed the Energy and Capacity rates listed above, but not
the CRC.
[FR Doc. 2021-24217 Filed 11-4-21; 8:45 am]
BILLING CODE 6450-01-P
