Pick-Sloan Missouri Basin Program-Eastern Division-Rate Order No. WAPA-217, 104143-104150 [2024-30361]
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Federal Register / Vol. 89, No. 245 / Friday, December 20, 2024 / Notices
f. Location: The project is located on
the North Fork Kings River in Fresno
County, California. The project occupies
Federal lands managed by the U.S.
Forest Service, U.S. Corps of Engineers,
and Bureau of Land Management.
g. Filed Pursuant to: Federal Power
Act, 16 U.S.C. 791a–825r.
h. Applicant Contact: Tiffany Begaye;
P.O. Box 28209, Oakland, California
94604; T9BC@pge.com; and (559) 955–
7135.
i. FERC Contact: Katherine Schmidt;
(415) 369–3348; and
katherine.schmidt@ferc.gov.
j. Cooperating Agencies: With this
notice, the Commission is inviting
Federal, State, local, and Tribal agencies
with jurisdiction and/or special
expertise with respect to environmental
issues affected by the proposal, that
wish to cooperate in the preparation of
any environmental document, if
applicable, to follow the instructions for
filing such requests described in item k
below. Cooperating agencies should
note the Commission’s policy that
agencies that cooperate in the
preparation of any environmental
document cannot also intervene. See 94
FERC ¶ 61,076 (2001).
k. Deadline for filing comments,
motions to intervene, and protests:
January 15, 2025.
The Commission strongly encourages
electronic filing. Please file comments,
motions to intervene, and protests using
the Commission’s eFiling system at
https://www.ferc.gov/docs-filing/
efiling.asp. Commenters can submit
brief comments up to 6,000 characters,
without prior registration, using the
eComment system at https://
www.ferc.gov/docs-filing/
ecomment.asp. For assistance, please
contact FERC Online Support at
FERCOnlineSupport@ferc.gov, (866)
208–3676 (toll free), or (202) 502–8659
(TTY). In lieu of electronic filing, you
may submit a paper copy. Submissions
sent via the U.S. Postal Service must be
addressed to: Debbie-Anne A. Reese,
Secretary, Federal Energy Regulatory
Commission, 888 First Street NE, Room
1A, Washington, DC 20426.
Submissions sent via any other carrier
must be addressed to: Debbie-Anne A.
Reese, Secretary, Federal Energy
Regulatory Commission, 12225 Wilkins
Avenue, Rockville, MD 20852. The first
page of any filing should include the
docket number P–1988–104. Comments
emailed to Commission staff are not
considered part of the Commission
record.
The Commission’s Rules of Practice
and Procedure require all intervenors
filing documents with the Commission
to serve a copy of that document on
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each person whose name appears on the
official service list for the project.
Further, if an intervenor files comments
or documents with the Commission
relating to the merits of an issue that
may affect the responsibilities of a
particular resource agency, they must
also serve a copy of the document on
that resource agency.
l. Description of Request: The licensee
requests a temporary variance of the
release requirements under Article 402
that require it, in part, to release from
the Kings penstock into Dinkey Creek a
minimum flow in dry water years of 15
cubic feet per second (cfs), and from
December 1 through May 31 in wet or
normal water year types, as measured at
gaging station the discharge point (KI–
31), and to ensure a minimum of 25 cfs
in the North Fork Kings River
downstream of Dinkey Creek. With the
variance, the licensee proposes to
eliminate the 15 cfs supplemental flow
releases from January 6 through May 31,
2025, to dewater the Kings River tunnel
and penstock to enable the replacement
and testing of a turbine shut-off valve.
The licensee states that natural flows
will still be present in Dinkey Creek
through this time and that it will ensure
the minimum requirement of 25 cfs in
the North Fork Kings River will be
maintained during the variance period.
m. Locations of the Application: This
filing may be viewed on the
Commission’s website at 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. You may
also register online at https://
www.ferc.gov/docs-filing/
esubscription.asp to be notified via
email of new filings and issuances
related to this or other pending projects.
For assistance, call 1–866–208–3676 or
email FERCOnlineSupport@ferc.gov, for
TTY, call (202) 502–8659. Agencies may
obtain copies of the application directly
from the applicant.
n. Individuals desiring to be included
on the Commission’s mailing list should
so indicate by writing to the Secretary
of the Commission.
o. Comments, Protests, or Motions to
Intervene: Anyone may submit
comments, a protest, or a motion to
intervene in accordance with the
requirements of Rules of Practice and
Procedure, 18 CFR 385.210, .211, .214,
respectively. In determining the
appropriate action to take, the
Commission will consider all protests or
other comments filed, but only those
who file a motion to intervene in
accordance with the Commission’s
Rules may become a party to the
proceeding. Any comments, protests, or
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104143
motions to intervene must be received
on or before the specified comment date
for the particular application.
p. Filing and Service of Documents:
Any filing must (1) bear in all capital
letters the title ‘‘COMMENTS’’,
‘‘PROTEST’’, or ‘‘MOTION TO
INTERVENE’’ as applicable; (2) set forth
in the heading the name of the applicant
and the project number of the
application to which the filing
responds; (3) furnish the name, address,
and telephone number of the person
commenting, protesting or intervening;
and (4) otherwise comply with the
requirements of 18 CFR 385.2001
through 385.2005. All comments,
motions to intervene, or protests must
set forth their evidentiary basis. Any
filing made by an intervenor must be
accompanied by proof of service on all
persons listed in the service list
prepared by the Commission in this
proceeding, in accordance with 18 CFR
385.2010.
q. The Commission’s Office of Public
Participation (OPP) supports meaningful
public engagement and participation in
Commission proceedings. OPP can help
members of the public, including
landowners, environmental justice
communities, Tribal members and
others, access publicly available
information and navigate Commission
processes. For public inquiries and
assistance with making filings such as
interventions, comments, or requests for
rehearing, the public is encouraged to
contact OPP at (202) 502–6595 or OPP@
ferc.gov.
Dated: December 16, 2024.
Debbie-Anne A. Reese,
Secretary.
[FR Doc. 2024–30467 Filed 12–19–24; 8:45 am]
BILLING CODE 6717–01–P
DEPARTMENT OF ENERGY
Western Area Power Administration
Pick-Sloan Missouri Basin Program—
Eastern Division—Rate Order No.
WAPA–217
Western Area Power
Administration, DOE.
ACTION: Notice of rate order.
AGENCY:
The extension of the Upper
Great Plains (UGP) region’s existing
Pick-Sloan Missouri Basin Program—
Eastern Division (P–SMBP—ED)
transmission and ancillary services
formula rates has been confirmed,
approved, and placed into effect on an
interim basis. The existing formula rates
under Rate Schedules WAUGP–ATRR
(Annual Transmission Revenue
SUMMARY:
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Requirement), WAUGP–AS1
(Scheduling, System Control, and
Dispatch Service), WAUW–AS3
(Regulation and Frequency Response
Service), WAUW–AS4 (Energy
Imbalance Service), WAUW–AS5
(Operating Reserve—Spinning Reserve
Service), WAUW–AS6 (Operating
Reserve—Supplemental Reserve
Service), and WAUW–AS7 (Generator
Imbalance Service) are set to expire on
September 30, 2025. This rate extension
makes no changes to the existing
formula rates and extends them through
September 30, 2030.
DATES: The extended formula rates
under Rate Schedules WAUGP–ATRR,
WAUGP–AS1, WAUW–AS3, WAUW–
AS4, WAUW–AS5, WAUW–AS6 and
WAUW–AS7 will be placed into effect
on an interim basis on October 1, 2025.
FOR FURTHER INFORMATION CONTACT: Mr.
Lloyd Linke, Regional Manager, Upper
Great Plains Region, Western Area
Power Administration, 2900 4th Avenue
North, Billings, MT 59101–1266; (406)
255–2800; email: lloyd@wapa.gov, or
Linda Cady-Hoffman, Rates Manager,
Upper Great Plains Region, telephone:
(406) 255–2920; email: cady@wapa.gov.
SUPPLEMENTARY INFORMATION: Western
Area Power Administration (WAPA)
published a Federal Register notice
(Proposed FRN) on August 26, 2024 (89
FR 68432), proposing to extend the
existing formula rates under Rate
Schedules WAUGP–ATRR, WAUGP–
AS1, WAUW–AS3, WAUW–AS4,
WAUW–AS5, WAUW–AS6 and
WAUW–AS7. The Proposed FRN also
initiated a 30-day public consultation
and comment period.
Legal Authority
By Delegation Order No. S1–DEL–
RATES–2016, 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
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 the Federal
Energy Regulatory Commission (FERC).
By Delegation Order No. S1–DEL–S3–
2024, effective August 30, 2024, the
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
Infrastructure. By Redelegation Order
No. S3–DEL–WAPA1–2023, effective
April 10, 2023, the Under Secretary for
Infrastructure further redelegated the
authority to confirm, approve, and place
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such rates into effect on an interim basis
to WAPA’s Administrator. This
extension is issued under Redelegation
Order No. S3–DEL–WAPA1–2023 and
Department of Energy rate extension
procedures set forth in 10 CFR part
903.1
Following review of UGP’s proposal,
Rate Order No. WAPA–217 is hereby
confirmed, approved, and placed into
effect on an interim basis. This extends,
without adjustment, the existing Rate
Schedules WAUGP–ATRR, WAUGP–
AS1, WAUW–AS3, WAUW–AS4,
WAUW–AS5, WAUW–AS6, and
WAUW–AS7 through September 30,
2030. WAPA will submit Rate Order No.
WAPA–217 and the extended rate
schedules 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, Extension for the
Pick-Sloan Missouri Basin Program—
Eastern Division Transmission and
Ancillary Services Formula Rates,
Rate Order No. WAPA–217
Order Confirming, Approving, and
Placing the Transmission and Ancillary
Services Formula Rates for the PickSloan Missouri Basin Program—
Eastern Division Into Effect on an
Interim Basis
The formula rates in Rate Order No.
WAPA–217 are established following
section 302 of the Department of Energy
(DOE) Organization Act (42 U.S.C.
7152).1
By Delegation Order No. S1–DEL–
RATES–2016, effective November 19,
2016, the Secretary of Energy delegated:
(1) the authority to develop power and
transmission rates to the Western Area
Power Administration (WAPA)
Administrator; (2) the authority to
confirm, approve, and place into effect
such rates on an interim basis to the
Deputy Secretary of Energy; and (3) the
authority to confirm, approve on a final
basis, or to remand or disapprove such
rates to the Federal Energy Regulatory
Commission (FERC). By Delegation
Order No. S1–DEL–S3–2024, effective
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 section
5 of the Flood Control Act of 1944 (16 U.S.C. 825s);
and other acts that specifically apply to the projects
involved.
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August 30, 2024, the Secretary of Energy
also delegated the authority to confirm,
approve, and place such rates into effect
on an interim basis to the Under
Secretary of Infrastructure. By
Redelegation Order No. S3–DEL–
WAPA1–2023, effective April 10, 2023,
the Under Secretary for Infrastructure
further redelegated the authority to
confirm, approve, and place such rates
into effect on an interim basis to
WAPA’s Administrator. This extension
is issued under the Redelegation Order
No. S3–DEL–WAPA1–2023 and DOE
rate extension procedures set forth at 10
CFR part 903.2
Background
On October 1, 2020, FERC approved
and confirmed Rate Schedules
WAUGP–ATRR (Annual Transmission
Revenue Requirement), WAUGP–AS1
(Scheduling, System Control, and
Dispatch Service), WAUW–AS3
(Regulation and Frequency Response
Service), WAUW–AS4 (Energy
Imbalance Service), WAUW–AS5
(Operating Reserve-Spinning Reserve
Service), WAUW–AS6 (Operating
Reserve-Supplemental Reserve Service),
and WAUW–AS7 (Generator Imbalance
Service) under Rate Order No. WAPA–
188 on a final basis for a 5-year period
through September 30, 2025.3 These rate
schedules apply to Pick-Sloan Missouri
Basin Program—Eastern Division (P–
SMBP—ED) transmission and ancillary
services formula rates. Details about the
rate schedules and the formula rates are
viewable on UGP’s Rates website at:
www.wapa.gov/about-wapa/regions/
ugp/ugp-rates/. The rates continue the
formula-based methodology that
includes an annual update to the data in
the rate formulas, which provide
adequate revenue to recover annual
expenses, including interest expense,
and repay capital investments within
allowable time periods. This ensures
repayment within the cost recovery
criteria set forth in DOE Order RA
6120.2.
Discussion
In accordance with 10 CFR 903.23(a),
UGP filed a notice in the Federal
Register on August 26, 2024, proposing
to extend, without adjustment, Rate
Schedules WAUGP–ATRR, WAUGP–
AS1, WAUW–AS3, WAUW–AS4,
WAUW–AS5, WAUW–AS6, and
WAUW–AS7 under Rate Order No.
WAPA–217.4 UGP determined it was
2 50 FR 37835 (Sept. 18, 1985) and 84 FR 5347
(Feb. 21, 2019).
3 Order Confirming and Approving Rate
Schedules on a Final Basis, FERC Docket No. EF20–
3–000 and EF20–3–001 (2020).
4 89 FR 68432 (2024).
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not necessary to hold public
information or public comment forums
on the proposed formula rate extension,
but provided a 30-day consultation and
comment period to give the public an
opportunity to comment on the
proposed extension. The consultation
and comment period ended on
September 25, 2024, and UGP received
no comments on the proposed formula
rate extension.
Ratemaking Procedure Requirements
Environmental Compliance
A categorical exclusion determination
was previously issued for these rates
under the following categorical
exclusion listed in appendix B to
subpart D of 10 CFR part 1021: B4.3
(Electric power marketing rate
changes).5 That categorical exclusion
determination is also applicable to this
rate action. A copy of the categorical
exclusion determination is available on
WAPA’s website at: www.wapa.gov/wpcontent/uploads/2024/10/RateExtension-RO-WAPA-217-CX09272024.pdf.
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.
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Submission to the Federal Energy
Regulatory Commission
The provisional formula rates 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–217, which extends the existing
UGP transmission and ancillary services
formula rates under Rate Schedules
WAUGP–ATRR, WAUGP–AS1,
WAUW–AS3, WAUW–AS4, WAUW–
AS5, WAUW–AS6, and WAUW–AS7
through September 30, 2030. The rates
will remain in effect on an interim basis
until: (1) FERC confirms and approves
of this extension on a final basis; (2)
subsequent rates are confirmed and
5 The determination was done in compliance with
the National Environmental Policy Act (NEPA) of
1969, as amended, 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).
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approved; or (3) such rates are
superseded.
Formula Rate
Signing Authority
This document of the Department of
Energy was signed on December 16,
2024, by Tracey A. 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.
A = Operation & Maintenance allocated
to transmission ($)
B = Depreciation allocated to
transmission ($)
C = Interest Expense allocated to
transmission ($)
D = Revenue Credits ($)
E = Scheduling, System Control, and
Dispatch costs ($)
F = Prior Period True-up ($)
ATRR = A + B + C¥D¥E + F
Define
Signed in Washington, DC, on December
16, 2024.
Treena V. Garrett,
Federal Register Liaison Officer, U.S.
Department of Energy.
Rate Schedule WAUGP–ATRR, October
1, 2025
(Supersedes Rate Schedule WAUGP–
ATRR Dated October 1, 2020, Through
September 30, 2025)
United States Department of Energy
Western Area Power Administration
Upper Great Plains Region Pick-Sloan
Missouri Basin Program—Eastern
Division
Annual Transmission Revenue
Requirement for Transmission Service
(Approved Under Rate Order No.
WAPA–188)
Effective
Beginning on October 1, 2020, and
remaining in effect through September
30, 2025, or until superseded by another
rate schedule, whichever occurs earlier.
Notification of the effective date of the
formula rates will be published in the
Federal Register. [Note: This rate
schedule was extended by Rate Order
No. WAPA–217 through September 30,
2030.]
Applicable
Western Area Power AdministrationUpper Great Plains (Western-UGP)
region’s formula based Annual
Transmission Revenue Requirement
(ATRR) for its eligible transmission
related facilities included under the
Southwest Power Pool, Inc. (SPP) Tariff
will be calculated using the formula
outlined below.
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Note: Western-UGP will identify any
portion(s) of the ATRR eligible for recovery
under SPP Schedule 11 pursuant to the SPP
Tariff in its Rate Formula Template
submitted under Attachment H of the SPP
Tariff.
A recalculated annual revenue
requirement will go into effect every
January 1 based on the above formula
and updated financial data. WesternUGP will annually notify SPP and make
data and information available to
interested parties for review and
comment related to the recalculated
annual revenue requirement on or
shortly after September 1 of the
preceding year. Data used and the
charges resulting from using this
formula will be posted on the applicable
SPP website and Western-UGP’s Open
Access Same-Time Information System
(OASIS).
Rate Schedule WAUGP–AS1, October 1,
2025
(Supersedes Rate Schedule WAUGP–
AS1 Dated October 1, 2020,Through
September 30, 2025)
United States Department of Energy
Western Area Power Administration
Upper Great Plains Region Pick-Sloan
Missouri Basin Program—Eastern
Division
Scheduling, System Control, and
Dispatch Service
(Approved Under Rate Order No.
WAPA–188)
Effective
Beginning on October 1, 2020, and
remaining in effect through September
30, 2025, or until superseded by another
rate schedule, whichever occurs earlier.
Notification of the effective date of the
formula rates will be published in the
Federal Register. [Note: This rate
schedule was extended by Rate Order
No. WAPA–217 through September 30,
2030.]
Applicable
Scheduling, System Control, and
Dispatch Service (SSCD) is required to
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schedule the movement of power
through, out of, within, or into the
Southwest Power Pool, Inc. (SPP)
Balancing Authority Area and/or the
Western Area Power Administration,
Upper Great Plains West Balancing
Authority Area (WAUW). Western Area
Power Administration-Upper Great
Plains (Western-UGP) region’s annual
revenue requirement for SSCD will be
used by SPP to calculate the regional
SPP Schedule 1 rate for SPP through
and out transactions, and also to
calculate the zonal SPP Schedule 1 rate
for the Upper Missouri Zone (UMZ or
Zone 19). This rate will also be charged
by SPP for SPP Transmission Service
provided within the UMZ in the
Western Interconnection.
Formula Rate
Define
A = Operation & Maintenance for SSCD
($)
B = Administrative and General
Expense for SSCD ($)
C = Depreciation for SSCD ($)
D = Taxes Other than Income Taxes for
Transmission ($)
E = Allocation of General Plant for
SSCD ($)
F = Cost of Capital for SSCD ($)
G = SSCD Revenue from nonTransmission facilities ($)
H = Prior Period True-up ($)
SSCD Annual Revenue Requirement = A
+ B + C + D + E + F¥G + H
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A recalculated annual revenue
requirement will go into effect every
January 1 based on the above formula
and updated financial data. WesternUGP will annually notify SPP and make
data and information available to
interested parties for review and
comment related to the recalculated
annual revenue requirement on or
shortly after September 1 of the
preceding year. Data used and the
charges resulting from using this
formula will be posted on the applicable
SPP website and Western-UGP’s Open
Access Same-Time Information System
(OASIS).
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Rate Schedule WAUW–AS3, October 1,
2025
(Supersedes Rate Schedule WAUW–
AS3 Dated October 1, 2020, Through
September 30, 2025)
United States Department of Energy
Western Area Power Administration
Upper Great Plains Region Pick-Sloan
Missouri Basin Program—Eastern
Division
Regulation and Frequency Response
Service—WAUW
(Approved Under Rate Order No.
WAPA–188)
Effective
Beginning on October 1, 2020, and
remaining in effect through September
30, 2025, or until superseded by another
rate schedule, whichever occurs earlier.
Notification of the effective date of the
formula rates will be published in the
Federal Register. [Note: This rate
schedule was extended by Rate Order
No. WAPA–217 through September 30,
2030.]
Applicable
This Rate Schedule applies to the
Western Area Power Administration,
Upper Great Plains West Balancing
Authority Area (WAUW). Regulation
and Frequency Response Service
(Regulation) is necessary to provide for
the continuous balancing of resources,
generation, and interchange with load
and for maintaining scheduled
interconnection frequency at 60 cycles
per second (60 Hz). Regulation is
accomplished by committing on-line
generation whose output is raised or
lowered, predominantly through the use
of automatic generating control
equipment, as necessary, to follow the
moment-by-moment changes in load.
The obligation to maintain this balance
between resources and load lies with
the Western Area Power
Administration-Upper Great Plains
(Western-UGP) region as the WAUW
operator. The SPP Transmission
Customer must either purchase this
service from SPP or make alternative
comparable arrangements pursuant to
the SPP Tariff to satisfy its Regulation
obligation. Western-UGP’s annual
revenue requirement for Regulation
(outlined below) will be used by SPP to
calculate the WAUW charges for
Regulation.
Western-UGP supports the
installation of renewable sources of
energy but recognizes that certain
operational constraints exist in
managing the significant fluctuations
that are a normal part of their operation.
When Western-UGP purchases power
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resources to provide Regulation to
intermittent resources serving load
within Western-UGP’s WAUW, costs for
these regulation resources will become
part of Western’s Regulation revenue
requirement, which will be billed by
SPP, as the Transmission Provider, to a
SPP Transmission Customer along with
the associated transmission service
provided by SPP under the SPP Tariff.
However, Western-UGP will not
regulate for the difference between the
output of an intermittent resource
located within Western- UGP’s WAUW
and a delivery schedule from that
generator serving load located outside of
Western-UGP’s WAUW. Intermittent
resources serving load outside WesternUGP’s WAUW will be required to be
pseudo-tied or dynamically scheduled
to another Balancing Authority Area.
An intermittent resource, for the
limited purpose of this Rate Schedule,
is an electric generator that is not
dispatchable and cannot store its fuel
source and, therefore, cannot respond to
changes in demand or respond to
transmission security constraints.
Formula Rate
Define
A = U.S. Army Corps of Engineers
(Corps) Fixed Charge Rate (%)
B = Corps Generation Net Plant Costs ($)
C = Plant Capacity (kW)
D = Capacity Used for Regulation (kWyear)
E = Capacity Purchases for Regulation
($)
F = Prior Period True-up
Regulation Annual Revenue
Requirement = (A * B/C) * D + E +
F
A recalculated revenue requirement
will go into effect every January 1 based
on the above formula and updated
financial data. Western-UGP will
annually notify SPP and make data and
information available to interested
parties for review and comment related
to the recalculated annual revenue
requirement on or shortly after
September 1 of the preceding year. Data
used and the charges resulting from
using this formula will be posted on the
applicable SPP website and WesternUGP’s Open Access Same-Time
Information System (OASIS).
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Rate Schedule WAUW–AS4, October 1,
2025
(Supersedes Rate Schedule WAUW–
AS4 Dated October 1, 2020, Through
September 30, 2025)
United States Department of Energy
Western Area Power Administration
Upper Great Plains Region Pick-Sloan
Missouri Basin Program—Eastern
Division
Energy Imbalance Service—WAUW
(Approved Under Rate Order No.
WAPA–188)
ddrumheller on DSK120RN23PROD with NOTICES1
Effective
Beginning on October 1, 2020, and
remaining in effect through September
30, 2025, or until superseded by another
rate schedule, whichever occurs earlier.
Notification of the effective date of the
formula rates will be published in the
Federal Register. [Note: This rate
schedule was extended by Rate Order
No. WAPA–217 through September 30,
2030.]
Applicable
This Rate Schedule applies to the
Western Area Power Administration,
Upper Great Plains West Balancing
Authority Area (WAUW). Energy
Imbalance Service is provided when a
difference occurs between scheduled
and actual delivery of energy to a load
located within Western Area Power
Administration-Upper Great Plains
(Western-UGP) region’s WAUW over a
single hour (or different dispatch
interval for energy imbalance service
market, if applicable). Given the
Southwest Power Pool, Inc. (SPP)
Integrated Marketplace does not extend
into the Western Interconnection,
Western-UGP, as the Balancing
Authority, will offer to provide Energy
Imbalance Service in the WAUW at the
request of SPP, if it is capable of doing
so, from its own resources or from
resources available to it including
possible participation in a Western
Interconnection energy imbalance
service market. SPP is the Transmission
Provider for the eligible Western-UGP
facilities transferred to the functional
control of SPP in the WAUW. Energy
Imbalance Service is needed when
transmission service is provided by SPP
and used to serve load within the
WAUW, or when a difference occurs
between the expected and actual
delivery of energy to/from the WAUW
over a single hour (or different dispatch
interval for energy imbalance service
market, if applicable) in the event that
Western-UGP participates in a Western
Interconnection energy imbalance
service market in the WAUW as the
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Jkt 265001
Balancing Authority. Energy Imbalance
Service in the WAUW will be billed by
SPP to the SPP Transmission Customer
along with the associated transmission
service provided by SPP. The SPP
Transmission Customer must either
purchase this service from SPP, or make
alternative comparable arrangements
pursuant to the SPP Tariff to satisfy its
Energy Imbalance Service obligation.
The SPP Transmission Customer will
incur a charge for either hourly energy
imbalances under this Schedule,
WAUW–AS4, or hourly generator
imbalances under Rate Schedule
WAUW–AS7 for imbalances occurring
during the same hour, but not both,
unless the imbalances aggravate rather
than offset each other.
Formula Rate
(A) In the event that Western-UGP
does not participate in a Western
Interconnection energy imbalance
service market in the WAUW as the
Balancing Authority, or such energy
imbalance market is unable to provide
the total energy imbalance requirements
for certain loads and generation within
the Balancing Authority Area:
For deviations within +/¥ 1.5 percent
(with a minimum of 2 MW) of the
scheduled transaction to be applied
hourly to any energy imbalance that
occurs as a result of the SPP
Transmission Customer’s scheduled
transaction(s) will be netted on a
monthly basis and settled financially, at
the end of the month, at 100 percent of
the average incremental cost.
Deviations greater than +/¥ 1.5
percent up to 7.5 percent (or greater
than 2 MW up to 10 MW) of the
scheduled transaction to be applied
hourly to any energy imbalance that
occurs as a result of the SPP
Transmission Customer’s scheduled
transaction(s) will be settled financially,
at the end of each month. When energy
taken in a schedule hour is greater than
the energy scheduled, the charge is 110
percent of incremental cost. When
energy taken is less than the scheduled
amount, the credit is 90 percent of the
incremental cost.
Deviations greater than +/¥ 7.5
percent (or 10 MW) of the scheduled
transaction to be applied hourly to any
energy imbalance that occurs as a result
of the SPP Transmission Customer’s
scheduled transaction(s) will be settled
at 125 percent of Western-UGP’s
incremental cost when energy taken in
a schedule hour is greater than the
energy scheduled or 75 percent of
Western- UGP’s incremental cost when
energy taken by a SPP Transmission
Customer is less than the scheduled
amount.
PO 00000
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Fmt 4703
Sfmt 4703
104147
Western-UGP’s incremental cost will
be based upon a representative hourly
energy index or combination of indexes.
The index to be used will be posted on
the applicable SPP website and
Western-UGP’s Open Access Same-Time
Information System (OASIS) at least 30
days before use for determining the
Western-UGP incremental cost and will
not be changed more often than once
per year unless Western-UGP
determines that the existing index is no
longer a reliable price index.
The pricing and charge for deviations
in the above deviation bandwidths is as
specified above. Data used and the
charges resulting from using this
formula will be posted on the applicable
SPP website and Western-UGP’s OASIS.
(B) In the event that Western-UGP
participates in a Western
Interconnection energy imbalance
service market in the WAUW as the
Balancing Authority:
Charges to the SPP Transmission
Customer will reflect only the passthrough of the applicable charges
associated with the Western
Interconnection energy imbalance
service market assessed to Western-UGP
as the WAUW Balancing Authority for
embedded load and/or generation in the
WAUW of such SPP Transmission
Customer that does not make adequate
alternate arrangements in such Western
Interconnection energy imbalance
service market or other alternative
comparable arrangements pursuant to
the SPP Tariff to satisfy its Energy
Imbalance Service obligation.
Western-UGP will post notice on the
applicable SPP website and WesternUGP’s OASIS, and also notify existing
SPP Transmission Customers, at least 30
days before Western-UGP participates in
a Western Interconnection energy
imbalance service market, as the
Balancing Authority. Western-UGP will
also post information related to the
charges assessed by the market operator
for Energy Imbalance Service in the
WAUW under such Western
Interconnection energy imbalance
service market.
Data used and the charges resulting
from using this formula will be posted
on the applicable SPP website and
Western-UGP’s OASIS.
E:\FR\FM\20DEN1.SGM
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104148
Federal Register / Vol. 89, No. 245 / Friday, December 20, 2024 / Notices
Rate Schedule WAUW–AS5, October 1,
2025
(Supersedes Rate Schedule WAUW–
AS5 Dated October 1, 2020, Through
September 30, 2025)
United States Department of Energy
Western Area Power Administration
Upper Great Plains Region Pick-Sloan
Missouri Basin Program—Eastern
Division
Operating Reserve—Spinning Reserve
Service—WAUW
(Approved Under Rate Order No.
WAPA–188)
Effective
Beginning on October 1, 2020, and
remaining in effect through September
30, 2025, or until superseded by another
rate schedule, whichever occurs earlier.
Notification of the effective date of the
formula rates will be published in the
Federal Register. [Note: This rate
schedule was extended by Rate Order
No. WAPA–217 through September 30,
2030.]
ddrumheller on DSK120RN23PROD with NOTICES1
Applicable
This Rate Schedule applies to the
Western Area Power Administration,
Upper Great Plains West Balancing
Authority Area (WAUW). Operating
Reserve-Spinning Reserve Service
(Spinning Reserves) is needed to serve
load immediately in the event of a
system contingency. Spinning Reserves
may be provided by generating units
that are on-line and loaded at less than
maximum output. Given the Southwest
Power Pool, Inc. (SPP) Integrated
Marketplace does not extend into the
Western Interconnection, Western Area
Power Administration-Upper Great
Plains (Western-UGP) region, as the
Balancing Authority, will offer to
provide Spinning Reserves, if available,
at the request of SPP as the
Transmission Provider in the WAUW.
Operating Reserve-Spinning Reserve
Service in the WAUW will be billed by
SPP to the SPP Transmission Customer
along with the associated transmission
service provided by SPP. The SPP
Transmission Customer must either
purchase this service from SPP or make
alternative comparable arrangements
pursuant to the SPP Tariff to satisfy its
Spinning Reserves obligation. WesternUGP’s annual revenue requirement for
Spinning Reserves (outlined below) will
be utilized by SPP to calculate the
WAUW charges for Spinning Reserves.
VerDate Sep<11>2014
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Jkt 265001
Formula Rate
Define
A = U.S. Army Corps of Engineers
(Corps) Fixed Charge Rate (%)
B = Corps Generation Net Plant Costs ($)
C = Plant Capacity (kW)
D = Maximum Load in the WAUW (kW)
E = Maximum Generation in the WAUW
(kW)
F = Reserve Sharing Program
Requirement based upon Load
(%)—See Note 1
G = Reserve Sharing Program
Requirement based upon
Generation (%)—See Note 2
H = Prior Period True-up
I = Annual cost associated with
Western-UGP’s current reserve
sharing group membership
Note 1: Currently 3% in the Northwest
Power Pool (NWPP) Reserve
Sharing Program
Note 2: Currently 3% in the NWPP
Reserve Sharing Program
Spinning Reserves Annual Revenue
Requirement = (A * B/C) * ((D * F)
+ (E * G)) + H + I
A recalculated revenue requirement
will go into effect every January 1 based
on the above formula and updated
financial, load/generation, and Reserve
Sharing Program requirements data.
Western-UGP will annually notify SPP
and make data and information
available to interested parties for review
and comment related to the recalculated
annual revenue requirement on or
shortly after September 1 of the
preceding year. Data used and the
charges resulting from using this
formula will be posted on the applicable
SPP website and Western-UGP’s Open
Access Same-Time Information System
(OASIS).
If resources are not available from a
Western-UGP resource, Western-UGP, at
the request of SPP as the Transmission
Provider, will offer to purchase the
Spinning Reserves and pass through the
costs, plus an amount for
administration, to SPP for the SPP
Transmission Customer.
In the event that Spinning Reserves
are called upon for emergency use, the
SPP Transmission Customer will be
assessed a charge for energy used at the
prevailing market energy rate in the
WAUW. The prevailing market energy
rate will be based upon a representative
hourly energy index or combination of
indexes. The index to be used will be
posted on the applicable SPP website
and Western-UGP’s OASIS at least 30
days before use for determining the
prevailing market energy rate and will
not be changed more often than once
per year unless Western-UGP
determines that the existing index is no
PO 00000
Frm 00077
Fmt 4703
Sfmt 4703
longer a reliable price index. The SPP
Transmission Customer would be
responsible for providing transmission
service to get the Spinning Reserves to
its destination.
Rate Schedule WAUW–AS6, October 1,
2025
(Supersedes Rate Schedule WAUW–
AS6 Dated October 1, 2020, Through
September 30, 2025)
United States Department of Energy
Western Area Power Administration
Upper Great Plains Region Pick-Sloan
Missouri Basin Program—Eastern
Division
Operating Reserve—Supplemental
Reserve Service—WAUW
(Approved Under Rate Order No.
WAPA–188)
Effective
Beginning on October 1, 2020, and
remaining in effect through September
30, 2025, or until superseded by another
rate schedule, whichever occurs earlier.
Notification of the effective date of the
formula rates will be published in the
Federal Register. [Note: This rate
schedule was extended by Rate Order
No. WAPA–217 through September 30,
2030.]
Applicable
This Rate Schedule applies to the
Western Area Power Administration,
Upper Great Plains West Balancing
Authority Area (WAUW). Operating
Reserve-Supplemental Reserve Service
(Supplemental Reserves) is needed to
serve load in the event of a system
contingency; however, it is not available
immediately to serve load but rather
within a short period of time.
Supplemental Reserves may be
provided by generating units that are
on-line but unloaded, by quick-start
generation, or by interruptible load.
Given the Southwest Power Pool, Inc.
(SPP) Integrated Marketplace does not
extend into the Western
Interconnection, Western Area Power
Administration-Upper Great Plains
(Western-UGP) region, as the Balancing
Authority, will offer to provide
Supplemental Reserves, if available, at
the request of SPP as the Transmission
Provider, in the WAUW. Operating
Reserve-Supplemental Reserve Service
in the WAUW will be billed by SPP to
the SPP Transmission Customer along
with the associated transmission service
provided by SPP. The SPP Transmission
Customer must either purchase this
service from SPP or make alternative
comparable arrangements pursuant to
the SPP Tariff to satisfy its
E:\FR\FM\20DEN1.SGM
20DEN1
Federal Register / Vol. 89, No. 245 / Friday, December 20, 2024 / Notices
Supplemental Reserves obligation.
Western-UGP’s annual revenue
requirement for Supplemental Reserves
(outlined below) will be utilized by SPP
to calculate the WAUW charges for
Supplemental Reserves.
Formula Rate
ddrumheller on DSK120RN23PROD with NOTICES1
Define
A = U.S. Army Corps of Engineers
(Corps) Fixed Charge Rate (%)
B = Corps Generation Net Plant Costs ($)
C = Plant Capacity (kW)
D = Maximum Load in the WAUW (kW)
E = Maximum Generation in the WAUW
(kW)
F = Reserve Sharing Program
Requirement based upon Load
(%)—See Note 1
G = Reserve Sharing Program
Requirement based upon
Generation (%)—See Note 2
H = Prior Period True-up
I = Annual cost associated with
Western-UGP’s current reserve
sharing group membership
Note 1: Currently 3% in the Northwest
Power Pool (NWPP) Reserve
Sharing Program
Note 2: Currently 3% in the NWPP
Reserve Sharing Program
Supplemental Reserves Annual Revenue
Requirement = (A * B/C) * ((D * F)
+ (E * G)) + H + I
A recalculated revenue requirement
will go into effect every January 1 based
on the above formula and updated
financial, load/generation, and Reserve
Sharing Program requirements data.
Western-UGP will annually notify SPP
and make data and information
available to interested parties for review
and comment related to the recalculated
annual revenue requirement on or
shortly after September 1 of the
preceding year. Data used and the
charges resulting from using this
formula will be posted on the applicable
SPP website and Western-UGP’s Open
Access Same-Time Information System
(OASIS).
If resources are not available from a
Western-UGP resource, Western-UGP, at
the request of SPP as the Transmission
Provider, will offer to purchase the
Supplemental Reserves and pass
through the costs, plus an amount for
administration, to SPP for the SPP
Transmission Customer.
In the event Supplemental Reserves
are called upon for emergency use, the
SPP Transmission Customer will be
assessed a charge for energy used at the
prevailing market energy rate in the
WAUW. The prevailing market energy
rate will be based upon a representative
hourly energy index or combination of
indexes. The index to be used will be
VerDate Sep<11>2014
20:12 Dec 19, 2024
Jkt 265001
posted on the applicable SPP website
and Western-UGP’s OASIS at least 30
days before use for determining the
prevailing market energy rate and will
not be changed more often than once
per year unless Western-UGP
determines that the existing index is no
longer a reliable price index. The SPP
Transmission Customer would be
responsible for providing transmission
service to get the Supplemental
Reserves to its destination.
Rate Schedule WAUW–AS7, October 1,
2025
(Supersedes Rate Schedule WAUW–
AS7 Dated October 1, 2020, Through
September 30, 2025)
United States Department of Energy
Western Area Power Administration
Upper Great Plains Region Pick-Sloan
Missouri Basin Program—Eastern
Division
Generator Imbalance Service—WAUW
(Approved Under Rate Order No.
WAPA–188)
Effective
Beginning on October 1, 2020, and
remaining in effect through September
30, 2025, or until superseded by another
rate schedule, whichever occurs earlier.
Notification of the effective date of the
formula rates will be published in the
Federal Register. [Note: This rate
schedule was extended by Rate Order
No. WAPA–217 through September 30,
2030.]
Applicable
This Rate Schedule applies to the
Western Area Power Administration,
Upper Great Plains West Balancing
Authority Area (WAUW). Generator
Imbalance Service is provided when a
difference occurs between the output of
a generator located within Western Area
Power Administration-Upper Great
Plains (Western-UGP) region’s WAUW
and a delivery schedule from that
generator to (1) another Balancing
Authority Area or (2) a load within
Western-UGP’s WAUW over a single
hour (or different dispatch interval for
energy imbalance service market, if
applicable). Given the Southwest Power
Pool, Inc. (SPP) Integrated Marketplace
does not extend into the Western
Interconnection, Western-UGP, as the
Balancing Authority, will offer to
provide this service at the request of
SPP, if it is capable of doing so, from its
own resources or from resources
available to it including possible
participation in a Western
Interconnection energy imbalance
service market. SPP is the Transmission
PO 00000
Frm 00078
Fmt 4703
Sfmt 4703
104149
Provider for the eligible Western-UGP
facilities transferred to the functional
control of SPP in the WAUW. Generator
Imbalance Service is needed when
transmission service is provided by SPP
and used to deliver energy from a
generator located within the WAUW, or
when a difference occurs between the
expected and actual delivery of energy
to/from the WAUW over a single hour
(or different dispatch interval for energy
imbalance service market, if applicable)
in the event that Western-UGP
participates in a Western
Interconnection energy imbalance
service market in the WAUW as the
Balancing Authority. Generator
Imbalance Service in the WAUW will be
billed by SPP to the SPP Transmission
Customer along with the associated
transmission service provided by SPP.
The SPP Transmission Customer must
either purchase this service from SPP or
make alternative comparable
arrangements pursuant to the SPP Tariff,
to satisfy its Generator Imbalance
Service obligation. The SPP
Transmission Customer will incur a
charge for either hourly generator
imbalances under this Schedule,
WAUW–AS7, or hourly energy
imbalances under Rate Schedule
WAUW–AS4 for imbalances occurring
during the same hour, but not both,
unless the imbalances aggravate rather
than offset each other.
Western-UGP supports the
installation of renewable sources of
energy but recognizes that certain
operational constraints exist in
managing the significant fluctuations
that are a normal part of their operation.
Western-UGP has marketed the
maximum practical amount of power
from each of its projects, leaving little or
no flexibility for provision of additional
power services. Consequently, WesternUGP will not regulate for the difference
between the output of an intermittent
resource located within the WAUW and
a delivery schedule from that generator
serving load located outside of the
WAUW. Intermittent resources serving
load outside Western-UGP’s WAUW
will be required to be pseudo-tied or
dynamically scheduled to another
Balancing Authority Area.
An intermittent resource, for the
limited purpose of this Rate Schedule,
is an electric generator that is not
dispatchable and cannot store its fuel
source and, therefore, cannot respond to
changes in demand or respond to
transmission security constraints.
Formula Rate
(A) In the event that Western-UGP
does not participate in a Western
Interconnection energy imbalance
E:\FR\FM\20DEN1.SGM
20DEN1
ddrumheller on DSK120RN23PROD with NOTICES1
104150
Federal Register / Vol. 89, No. 245 / Friday, December 20, 2024 / Notices
service market in the WAUW as the
Balancing Authority, or such energy
imbalance market is unable to provide
the total energy imbalance requirements
for certain loads and generation within
the Balancing Authority Area:
For deviations within +/¥ 1.5 percent
(with a minimum of 2 MW) of the
scheduled transaction to be applied
hourly to any generator imbalance that
occurs as a result of the SPP
Transmission Customer’s scheduled
transaction(s) will be netted on a
monthly basis and settled financially, at
the end of the month, at 100 percent of
the average incremental cost.
Deviations greater than +/¥ 1.5
percent up to 7.5 percent (or greater
than 2 MW up to 10 MW) of the
scheduled transaction to be applied
hourly to any generator imbalance that
occurs as a result of the SPP
Transmission Customer’s scheduled
transaction(s) will be settled financially,
at the end of each month. When energy
delivered in a schedule hour from the
generation resource is less than the
energy scheduled, the charge is 110
percent of incremental cost. When
energy delivered from the generation
resource is greater than the scheduled
amount, the credit is 90 percent of the
incremental cost.
Deviations greater than +/¥ 7.5
percent (or 10 MW) of the scheduled
transaction to be applied hourly to any
generator imbalance that occurs as a
result of the SPP Transmission
Customer’s scheduled transaction(s)
will be settled at 125 percent of
Western-UGP’s highest incremental cost
for the day when energy delivered in a
schedule hour is less than the energy
scheduled or 75 percent of WesternUGP’s lowest daily incremental cost
when energy delivered from the
generation resource is greater than the
scheduled amount. As an exception, an
intermittent resource will be exempt
from this deviation band and will pay
the deviation band charges for all
deviations greater than the larger of 1.5
percent or 2 MW.
Deviations from scheduled
transactions responding to directives by
the Transmission Provider, a Balancing
Authority, or a reliability coordinator
will not be subject to the deviation
bands identified above and, instead,
will be settled financially, at the end of
the month, at 100 percent of
incremental cost. Such directives may
include instructions to correct
frequency decay, respond to a reserve
sharing event, or change output to
relieve congestion.
Western-UGP’s incremental cost will
be based upon a representative hourly
energy index or combination of indexes.
VerDate Sep<11>2014
20:12 Dec 19, 2024
Jkt 265001
The index to be used will be posted on
the applicable SPP website and
Western-UGP’s Open Access Same-Time
Information System (OASIS) at least 30
days before use for determining the
Western-UGP incremental cost and will
not be changed more often than once
per year unless Western-UGP
determines that the existing index is no
longer a reliable price index.
The pricing and charge for deviations
in the deviation bandwidths is as
specified above. Data used and the
charges resulting from using this
formula will be posted on the applicable
SPP website and Western-UGP’s OASIS.
(B) In the event that Western-UGP
participates in a Western
Interconnection energy imbalance
service market in the WAUW as the
Balancing Authority:
Charges to the SPP Transmission
Customer will reflect only the passthrough of the applicable charges
associated with the Western
Interconnection energy imbalance
service market assessed to Western-UGP
as the WAUW Balancing Authority for
embedded load and/or generation in the
WAUW of such SPP Transmission
Customer that does not make adequate
alternate arrangements in such Western
Interconnection energy imbalance
service market or other alternative
comparable arrangements pursuant to
the SPP Tariff to satisfy its Generator
Imbalance Service obligation.
Western-UGP will post notice on the
applicable SPP website and WesternUGP’s OASIS, and also notify existing
Transmission Customers, at least 30
days before Western-UGP participates in
a Western Interconnection energy
imbalance service market, as the
Balancing Authority. Western-UGP will
also post information related to the
charges assessed by the market operator
for Generator Imbalance Service in the
WAUW under such Western
Interconnection energy imbalance
service market.
Data used and the charges resulting
from using this formula will be posted
on the applicable SPP website and
Western-UGP’s OASIS.
[FR Doc. 2024–30361 Filed 12–19–24; 8:45 am]
BILLING CODE 6450–01–P
ENVIRONMENTAL PROTECTION
AGENCY
[FRL OP–OFA–157]
Environmental Impact Statements;
Notice of Availability
Responsible Agency: Office of Federal
Activities, General Information 202–
564–5632 or https://www.epa.gov/nepa.
PO 00000
Frm 00079
Fmt 4703
Sfmt 9990
Weekly receipt of Environmental Impact
Statements (EIS)
Filed December 9, 2024 10 a.m. EST
Through December 16, 2024 10 a.m.
EST
Pursuant to 40 CFR 1506.9.
Notice
Section 309(a) of the Clean Air Act
requires that EPA make public its
comments on EISs issued by other
Federal agencies. EPA’s comment letters
on EISs are available at: https://
cdxapps.epa.gov/cdx-enepa-II/public/
action/eis/search.
EIS No. 20240236, Draft, USA, NC,
MOTSU Real Property Master Plan
Implementation, Comment Period
Ends: 02/04/2025, Contact: Adrienne
Rogers 571–644–8909.
EIS No. 20240237, Final, DOE, AK,
ADOPTION—Angoon Hydroelectric
Project Construction and Operation
Special-Use-Authorization Thayer
Creek Admiralty Island National
Monument Tongass National Forest
AK, Review Period Ends: 01/21/2025,
Contact: Gretchen Applegate 240–
252–0399.
The Department of Energy (DOE) has
adopted the Forest Service’s Final EIS
No. 20090068 filed 03/11/2009 with the
Environmental Protection Agency. The
DOE was not a cooperating agency on
this project. Therefore, republication of
the document is necessary under
Section 1506.3(b)(1) of the CEQ
regulations.
EIS No. 20240238, Final, USFS, NM,
South Sacramento Restoration Project,
Review Period Ends: 02/18/2025,
Contact: David Baker 541–671–1023.
EIS No. 20240239, Draft, BLM, ID,
Caldwell Canyon Revised Mine and
Reclamation Plan, Comment Period
Ends: 02/03/2025, Contact: Barry
Myers 208–559–3662.
EIS No. 20240240, Revised Draft,
USACE, NJ, New Jersey Back Bays
Coastal Storm Risk Management
Supplemental Draft Integrated
Feasibility Report and Environmental
Impact Statement, Comment Period
Ends: 02/18/2025, Contact: Steven D.
Allen 215–656–6559.
Dated: December 16, 2024.
Mark Austin,
Acting Director, NEPA Compliance Division,
Office of Federal Activities.
[FR Doc. 2024–30399 Filed 12–19–24; 8:45 am]
BILLING CODE 6560–50–P
E:\FR\FM\20DEN1.SGM
20DEN1
Agencies
[Federal Register Volume 89, Number 245 (Friday, December 20, 2024)]
[Notices]
[Pages 104143-104150]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 2024-30361]
-----------------------------------------------------------------------
DEPARTMENT OF ENERGY
Western Area Power Administration
Pick-Sloan Missouri Basin Program--Eastern Division--Rate Order
No. WAPA-217
AGENCY: Western Area Power Administration, DOE.
ACTION: Notice of rate order.
-----------------------------------------------------------------------
SUMMARY: The extension of the Upper Great Plains (UGP) region's
existing Pick-Sloan Missouri Basin Program--Eastern Division (P-SMBP--
ED) transmission and ancillary services formula rates has been
confirmed, approved, and placed into effect on an interim basis. The
existing formula rates under Rate Schedules WAUGP-ATRR (Annual
Transmission Revenue
[[Page 104144]]
Requirement), WAUGP-AS1 (Scheduling, System Control, and Dispatch
Service), WAUW-AS3 (Regulation and Frequency Response Service), WAUW-
AS4 (Energy Imbalance Service), WAUW-AS5 (Operating Reserve--Spinning
Reserve Service), WAUW-AS6 (Operating Reserve--Supplemental Reserve
Service), and WAUW-AS7 (Generator Imbalance Service) are set to expire
on September 30, 2025. This rate extension makes no changes to the
existing formula rates and extends them through September 30, 2030.
DATES: The extended formula rates under Rate Schedules WAUGP-ATRR,
WAUGP-AS1, WAUW-AS3, WAUW-AS4, WAUW-AS5, WAUW-AS6 and WAUW-AS7 will be
placed into effect on an interim basis on October 1, 2025.
FOR FURTHER INFORMATION CONTACT: Mr. Lloyd Linke, Regional Manager,
Upper Great Plains Region, Western Area Power Administration, 2900 4th
Avenue North, Billings, MT 59101-1266; (406) 255-2800; email:
[email protected], or Linda Cady-Hoffman, Rates Manager, Upper Great
Plains Region, telephone: (406) 255-2920; email: [email protected].
SUPPLEMENTARY INFORMATION: Western Area Power Administration (WAPA)
published a Federal Register notice (Proposed FRN) on August 26, 2024
(89 FR 68432), proposing to extend the existing formula rates under
Rate Schedules WAUGP-ATRR, WAUGP-AS1, WAUW-AS3, WAUW-AS4, WAUW-AS5,
WAUW-AS6 and WAUW-AS7. The Proposed FRN also initiated a 30-day public
consultation and comment period.
Legal Authority
By Delegation Order No. S1-DEL-RATES-2016, 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 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 the Federal Energy Regulatory
Commission (FERC). By Delegation Order No. S1-DEL-S3-2024, effective
August 30, 2024, the 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 Infrastructure. By Redelegation Order
No. S3-DEL-WAPA1-2023, effective April 10, 2023, the Under Secretary
for Infrastructure further redelegated the authority to confirm,
approve, and place such rates into effect on an interim basis to WAPA's
Administrator. This extension is issued under Redelegation Order No.
S3-DEL-WAPA1-2023 and Department of Energy rate extension procedures
set forth in 10 CFR part 903.\1\
---------------------------------------------------------------------------
\1\ 50 FR 37835 (Sept. 18, 1985) and 84 FR 5347 (Feb. 21, 2019).
---------------------------------------------------------------------------
Following review of UGP's proposal, Rate Order No. WAPA-217 is
hereby confirmed, approved, and placed into effect on an interim basis.
This extends, without adjustment, the existing Rate Schedules WAUGP-
ATRR, WAUGP-AS1, WAUW-AS3, WAUW-AS4, WAUW-AS5, WAUW-AS6, and WAUW-AS7
through September 30, 2030. WAPA will submit Rate Order No. WAPA-217
and the extended rate schedules 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, Extension for the
Pick-Sloan Missouri Basin Program--Eastern Division Transmission and
Ancillary Services Formula Rates, Rate Order No. WAPA-217
Order Confirming, Approving, and Placing the Transmission and Ancillary
Services Formula Rates for the Pick-Sloan Missouri Basin Program--
Eastern Division Into Effect on an Interim Basis
The formula rates in Rate Order No. WAPA-217 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 section 5 of the Flood Control Act of 1944 (16 U.S.C.
825s); and other acts that specifically apply to the projects
involved.
---------------------------------------------------------------------------
By Delegation Order No. S1-DEL-RATES-2016, effective November 19,
2016, the Secretary of Energy delegated: (1) the authority to develop
power and transmission rates to the Western Area Power Administration
(WAPA) Administrator; (2) the authority to confirm, approve, and place
into effect such rates on an interim basis to the Deputy Secretary of
Energy; and (3) the authority to confirm, approve on a final basis, or
to remand or disapprove such rates to the Federal Energy Regulatory
Commission (FERC). By Delegation Order No. S1-DEL-S3-2024, effective
August 30, 2024, the Secretary of Energy also delegated the authority
to confirm, approve, and place such rates into effect on an interim
basis to the Under Secretary of Infrastructure. By Redelegation Order
No. S3-DEL-WAPA1-2023, effective April 10, 2023, the Under Secretary
for Infrastructure further redelegated the authority to confirm,
approve, and place such rates into effect on an interim basis to WAPA's
Administrator. This extension is issued under the Redelegation Order
No. S3-DEL-WAPA1-2023 and DOE rate extension procedures set forth at 10
CFR part 903.\2\
---------------------------------------------------------------------------
\2\ 50 FR 37835 (Sept. 18, 1985) and 84 FR 5347 (Feb. 21, 2019).
---------------------------------------------------------------------------
Background
On October 1, 2020, FERC approved and confirmed Rate Schedules
WAUGP-ATRR (Annual Transmission Revenue Requirement), WAUGP-AS1
(Scheduling, System Control, and Dispatch Service), WAUW-AS3
(Regulation and Frequency Response Service), WAUW-AS4 (Energy Imbalance
Service), WAUW-AS5 (Operating Reserve-Spinning Reserve Service), WAUW-
AS6 (Operating Reserve-Supplemental Reserve Service), and WAUW-AS7
(Generator Imbalance Service) under Rate Order No. WAPA-188 on a final
basis for a 5-year period through September 30, 2025.\3\ These rate
schedules apply to Pick-Sloan Missouri Basin Program--Eastern Division
(P-SMBP--ED) transmission and ancillary services formula rates. Details
about the rate schedules and the formula rates are viewable on UGP's
Rates website at: www.wapa.gov/about-wapa/regions/ugp/ugp-rates/. The
rates continue the formula-based methodology that includes an annual
update to the data in the rate formulas, which provide adequate revenue
to recover annual expenses, including interest expense, and repay
capital investments within allowable time periods. This ensures
repayment within the cost recovery criteria set forth in DOE Order RA
6120.2.
---------------------------------------------------------------------------
\3\ Order Confirming and Approving Rate Schedules on a Final
Basis, FERC Docket No. EF20-3-000 and EF20-3-001 (2020).
---------------------------------------------------------------------------
Discussion
In accordance with 10 CFR 903.23(a), UGP filed a notice in the
Federal Register on August 26, 2024, proposing to extend, without
adjustment, Rate Schedules WAUGP-ATRR, WAUGP-AS1, WAUW-AS3, WAUW-AS4,
WAUW-AS5, WAUW-AS6, and WAUW-AS7 under Rate Order No. WAPA-217.\4\ UGP
determined it was
[[Page 104145]]
not necessary to hold public information or public comment forums on
the proposed formula rate extension, but provided a 30-day consultation
and comment period to give the public an opportunity to comment on the
proposed extension. The consultation and comment period ended on
September 25, 2024, and UGP received no comments on the proposed
formula rate extension.
---------------------------------------------------------------------------
\4\ 89 FR 68432 (2024).
---------------------------------------------------------------------------
Ratemaking Procedure Requirements
Environmental Compliance
A categorical exclusion determination was previously issued for
these rates under the following categorical exclusion listed in
appendix B to subpart D of 10 CFR part 1021: B4.3 (Electric power
marketing rate changes).\5\ That categorical exclusion determination is
also applicable to this rate action. A copy of the categorical
exclusion determination is available on WAPA's website at:
www.wapa.gov/wp-content/uploads/2024/10/Rate-Extension-RO-WAPA-217-CX-09272024.pdf.
---------------------------------------------------------------------------
\5\ The determination was done in compliance with the National
Environmental Policy Act (NEPA) of 1969, as amended, 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 formula rates 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-217, which extends the existing UGP transmission
and ancillary services formula rates under Rate Schedules WAUGP-ATRR,
WAUGP-AS1, WAUW-AS3, WAUW-AS4, WAUW-AS5, WAUW-AS6, and WAUW-AS7 through
September 30, 2030. The rates will remain in effect on an interim basis
until: (1) FERC confirms and approves of this extension 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 December
16, 2024, by Tracey A. 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 December 16, 2024.
Treena V. Garrett,
Federal Register Liaison Officer, U.S. Department of Energy.
Rate Schedule WAUGP-ATRR, October 1, 2025
(Supersedes Rate Schedule WAUGP-ATRR Dated October 1, 2020, Through
September 30, 2025)
United States Department of Energy Western Area Power Administration
Upper Great Plains Region Pick-Sloan Missouri Basin Program--Eastern
Division
Annual Transmission Revenue Requirement for Transmission Service
(Approved Under Rate Order No. WAPA-188)
Effective
Beginning on October 1, 2020, and remaining in effect through
September 30, 2025, or until superseded by another rate schedule,
whichever occurs earlier. Notification of the effective date of the
formula rates will be published in the Federal Register. [Note: This
rate schedule was extended by Rate Order No. WAPA-217 through September
30, 2030.]
Applicable
Western Area Power Administration-Upper Great Plains (Western-UGP)
region's formula based Annual Transmission Revenue Requirement (ATRR)
for its eligible transmission related facilities included under the
Southwest Power Pool, Inc. (SPP) Tariff will be calculated using the
formula outlined below.
Formula Rate
Define
A = Operation & Maintenance allocated to transmission ($)
B = Depreciation allocated to transmission ($)
C = Interest Expense allocated to transmission ($)
D = Revenue Credits ($)
E = Scheduling, System Control, and Dispatch costs ($)
F = Prior Period True-up ($)
ATRR = A + B + C-D-E + F
Note: Western-UGP will identify any portion(s) of the ATRR
eligible for recovery under SPP Schedule 11 pursuant to the SPP
Tariff in its Rate Formula Template submitted under Attachment H of
the SPP Tariff.
A recalculated annual revenue requirement will go into effect every
January 1 based on the above formula and updated financial data.
Western-UGP will annually notify SPP and make data and information
available to interested parties for review and comment related to the
recalculated annual revenue requirement on or shortly after September 1
of the preceding year. Data used and the charges resulting from using
this formula will be posted on the applicable SPP website and Western-
UGP's Open Access Same-Time Information System (OASIS).
Rate Schedule WAUGP-AS1, October 1, 2025
(Supersedes Rate Schedule WAUGP-AS1 Dated October 1, 2020,Through
September 30, 2025)
United States Department of Energy Western Area Power Administration
Upper Great Plains Region Pick-Sloan Missouri Basin Program--Eastern
Division
Scheduling, System Control, and Dispatch Service
(Approved Under Rate Order No. WAPA-188)
Effective
Beginning on October 1, 2020, and remaining in effect through
September 30, 2025, or until superseded by another rate schedule,
whichever occurs earlier. Notification of the effective date of the
formula rates will be published in the Federal Register. [Note: This
rate schedule was extended by Rate Order No. WAPA-217 through September
30, 2030.]
Applicable
Scheduling, System Control, and Dispatch Service (SSCD) is required
to
[[Page 104146]]
schedule the movement of power through, out of, within, or into the
Southwest Power Pool, Inc. (SPP) Balancing Authority Area and/or the
Western Area Power Administration, Upper Great Plains West Balancing
Authority Area (WAUW). Western Area Power Administration-Upper Great
Plains (Western-UGP) region's annual revenue requirement for SSCD will
be used by SPP to calculate the regional SPP Schedule 1 rate for SPP
through and out transactions, and also to calculate the zonal SPP
Schedule 1 rate for the Upper Missouri Zone (UMZ or Zone 19). This rate
will also be charged by SPP for SPP Transmission Service provided
within the UMZ in the Western Interconnection.
Formula Rate
Define
A = Operation & Maintenance for SSCD ($)
B = Administrative and General Expense for SSCD ($)
C = Depreciation for SSCD ($)
D = Taxes Other than Income Taxes for Transmission ($)
E = Allocation of General Plant for SSCD ($)
F = Cost of Capital for SSCD ($)
G = SSCD Revenue from non-Transmission facilities ($)
H = Prior Period True-up ($)
SSCD Annual Revenue Requirement = A + B + C + D + E + F-G + H
A recalculated annual revenue requirement will go into effect every
January 1 based on the above formula and updated financial data.
Western-UGP will annually notify SPP and make data and information
available to interested parties for review and comment related to the
recalculated annual revenue requirement on or shortly after September 1
of the preceding year. Data used and the charges resulting from using
this formula will be posted on the applicable SPP website and Western-
UGP's Open Access Same-Time Information System (OASIS).
Rate Schedule WAUW-AS3, October 1, 2025
(Supersedes Rate Schedule WAUW-AS3 Dated October 1, 2020, Through
September 30, 2025)
United States Department of Energy Western Area Power Administration
Upper Great Plains Region Pick-Sloan Missouri Basin Program--Eastern
Division
Regulation and Frequency Response Service--WAUW
(Approved Under Rate Order No. WAPA-188)
Effective
Beginning on October 1, 2020, and remaining in effect through
September 30, 2025, or until superseded by another rate schedule,
whichever occurs earlier. Notification of the effective date of the
formula rates will be published in the Federal Register. [Note: This
rate schedule was extended by Rate Order No. WAPA-217 through September
30, 2030.]
Applicable
This Rate Schedule applies to the Western Area Power
Administration, Upper Great Plains West Balancing Authority Area
(WAUW). Regulation and Frequency Response Service (Regulation) is
necessary to provide for the continuous balancing of resources,
generation, and interchange with load and for maintaining scheduled
interconnection frequency at 60 cycles per second (60 Hz). Regulation
is accomplished by committing on-line generation whose output is raised
or lowered, predominantly through the use of automatic generating
control equipment, as necessary, to follow the moment-by-moment changes
in load. The obligation to maintain this balance between resources and
load lies with the Western Area Power Administration-Upper Great Plains
(Western-UGP) region as the WAUW operator. The SPP Transmission
Customer must either purchase this service from SPP or make alternative
comparable arrangements pursuant to the SPP Tariff to satisfy its
Regulation obligation. Western-UGP's annual revenue requirement for
Regulation (outlined below) will be used by SPP to calculate the WAUW
charges for Regulation.
Western-UGP supports the installation of renewable sources of
energy but recognizes that certain operational constraints exist in
managing the significant fluctuations that are a normal part of their
operation. When Western-UGP purchases power resources to provide
Regulation to intermittent resources serving load within Western-UGP's
WAUW, costs for these regulation resources will become part of
Western's Regulation revenue requirement, which will be billed by SPP,
as the Transmission Provider, to a SPP Transmission Customer along with
the associated transmission service provided by SPP under the SPP
Tariff. However, Western-UGP will not regulate for the difference
between the output of an intermittent resource located within Western-
UGP's WAUW and a delivery schedule from that generator serving load
located outside of Western-UGP's WAUW. Intermittent resources serving
load outside Western-UGP's WAUW will be required to be pseudo-tied or
dynamically scheduled to another Balancing Authority Area.
An intermittent resource, for the limited purpose of this Rate
Schedule, is an electric generator that is not dispatchable and cannot
store its fuel source and, therefore, cannot respond to changes in
demand or respond to transmission security constraints.
Formula Rate
Define
A = U.S. Army Corps of Engineers (Corps) Fixed Charge Rate (%)
B = Corps Generation Net Plant Costs ($)
C = Plant Capacity (kW)
D = Capacity Used for Regulation (kW-year)
E = Capacity Purchases for Regulation ($)
F = Prior Period True-up
Regulation Annual Revenue Requirement = (A * B/C) * D + E + F
A recalculated revenue requirement will go into effect every
January 1 based on the above formula and updated financial data.
Western-UGP will annually notify SPP and make data and information
available to interested parties for review and comment related to the
recalculated annual revenue requirement on or shortly after September 1
of the preceding year. Data used and the charges resulting from using
this formula will be posted on the applicable SPP website and Western-
UGP's Open Access Same-Time Information System (OASIS).
[[Page 104147]]
Rate Schedule WAUW-AS4, October 1, 2025
(Supersedes Rate Schedule WAUW-AS4 Dated October 1, 2020, Through
September 30, 2025)
United States Department of Energy Western Area Power Administration
Upper Great Plains Region Pick-Sloan Missouri Basin Program--Eastern
Division
Energy Imbalance Service--WAUW
(Approved Under Rate Order No. WAPA-188)
Effective
Beginning on October 1, 2020, and remaining in effect through
September 30, 2025, or until superseded by another rate schedule,
whichever occurs earlier. Notification of the effective date of the
formula rates will be published in the Federal Register. [Note: This
rate schedule was extended by Rate Order No. WAPA-217 through September
30, 2030.]
Applicable
This Rate Schedule applies to the Western Area Power
Administration, Upper Great Plains West Balancing Authority Area
(WAUW). Energy Imbalance Service is provided when a difference occurs
between scheduled and actual delivery of energy to a load located
within Western Area Power Administration-Upper Great Plains (Western-
UGP) region's WAUW over a single hour (or different dispatch interval
for energy imbalance service market, if applicable). Given the
Southwest Power Pool, Inc. (SPP) Integrated Marketplace does not extend
into the Western Interconnection, Western-UGP, as the Balancing
Authority, will offer to provide Energy Imbalance Service in the WAUW
at the request of SPP, if it is capable of doing so, from its own
resources or from resources available to it including possible
participation in a Western Interconnection energy imbalance service
market. SPP is the Transmission Provider for the eligible Western-UGP
facilities transferred to the functional control of SPP in the WAUW.
Energy Imbalance Service is needed when transmission service is
provided by SPP and used to serve load within the WAUW, or when a
difference occurs between the expected and actual delivery of energy
to/from the WAUW over a single hour (or different dispatch interval for
energy imbalance service market, if applicable) in the event that
Western-UGP participates in a Western Interconnection energy imbalance
service market in the WAUW as the Balancing Authority. Energy Imbalance
Service in the WAUW will be billed by SPP to the SPP Transmission
Customer along with the associated transmission service provided by
SPP. The SPP Transmission Customer must either purchase this service
from SPP, or make alternative comparable arrangements pursuant to the
SPP Tariff to satisfy its Energy Imbalance Service obligation.
The SPP Transmission Customer will incur a charge for either hourly
energy imbalances under this Schedule, WAUW-AS4, or hourly generator
imbalances under Rate Schedule WAUW-AS7 for imbalances occurring during
the same hour, but not both, unless the imbalances aggravate rather
than offset each other.
Formula Rate
(A) In the event that Western-UGP does not participate in a Western
Interconnection energy imbalance service market in the WAUW as the
Balancing Authority, or such energy imbalance market is unable to
provide the total energy imbalance requirements for certain loads and
generation within the Balancing Authority Area:
For deviations within +/- 1.5 percent (with a minimum of 2 MW) of
the scheduled transaction to be applied hourly to any energy imbalance
that occurs as a result of the SPP Transmission Customer's scheduled
transaction(s) will be netted on a monthly basis and settled
financially, at the end of the month, at 100 percent of the average
incremental cost.
Deviations greater than +/- 1.5 percent up to 7.5 percent (or
greater than 2 MW up to 10 MW) of the scheduled transaction to be
applied hourly to any energy imbalance that occurs as a result of the
SPP Transmission Customer's scheduled transaction(s) will be settled
financially, at the end of each month. When energy taken in a schedule
hour is greater than the energy scheduled, the charge is 110 percent of
incremental cost. When energy taken is less than the scheduled amount,
the credit is 90 percent of the incremental cost.
Deviations greater than +/- 7.5 percent (or 10 MW) of the scheduled
transaction to be applied hourly to any energy imbalance that occurs as
a result of the SPP Transmission Customer's scheduled transaction(s)
will be settled at 125 percent of Western-UGP's incremental cost when
energy taken in a schedule hour is greater than the energy scheduled or
75 percent of Western- UGP's incremental cost when energy taken by a
SPP Transmission Customer is less than the scheduled amount.
Western-UGP's incremental cost will be based upon a representative
hourly energy index or combination of indexes. The index to be used
will be posted on the applicable SPP website and Western-UGP's Open
Access Same-Time Information System (OASIS) at least 30 days before use
for determining the Western-UGP incremental cost and will not be
changed more often than once per year unless Western-UGP determines
that the existing index is no longer a reliable price index.
The pricing and charge for deviations in the above deviation
bandwidths is as specified above. Data used and the charges resulting
from using this formula will be posted on the applicable SPP website
and Western-UGP's OASIS.
(B) In the event that Western-UGP participates in a Western
Interconnection energy imbalance service market in the WAUW as the
Balancing Authority:
Charges to the SPP Transmission Customer will reflect only the
pass-through of the applicable charges associated with the Western
Interconnection energy imbalance service market assessed to Western-UGP
as the WAUW Balancing Authority for embedded load and/or generation in
the WAUW of such SPP Transmission Customer that does not make adequate
alternate arrangements in such Western Interconnection energy imbalance
service market or other alternative comparable arrangements pursuant to
the SPP Tariff to satisfy its Energy Imbalance Service obligation.
Western-UGP will post notice on the applicable SPP website and
Western-UGP's OASIS, and also notify existing SPP Transmission
Customers, at least 30 days before Western-UGP participates in a
Western Interconnection energy imbalance service market, as the
Balancing Authority. Western-UGP will also post information related to
the charges assessed by the market operator for Energy Imbalance
Service in the WAUW under such Western Interconnection energy imbalance
service market.
Data used and the charges resulting from using this formula will be
posted on the applicable SPP website and Western-UGP's OASIS.
[[Page 104148]]
Rate Schedule WAUW-AS5, October 1, 2025
(Supersedes Rate Schedule WAUW-AS5 Dated October 1, 2020, Through
September 30, 2025)
United States Department of Energy Western Area Power Administration
Upper Great Plains Region Pick-Sloan Missouri Basin Program--Eastern
Division
Operating Reserve--Spinning Reserve Service--WAUW
(Approved Under Rate Order No. WAPA-188)
Effective
Beginning on October 1, 2020, and remaining in effect through
September 30, 2025, or until superseded by another rate schedule,
whichever occurs earlier. Notification of the effective date of the
formula rates will be published in the Federal Register. [Note: This
rate schedule was extended by Rate Order No. WAPA-217 through September
30, 2030.]
Applicable
This Rate Schedule applies to the Western Area Power
Administration, Upper Great Plains West Balancing Authority Area
(WAUW). Operating Reserve-Spinning Reserve Service (Spinning Reserves)
is needed to serve load immediately in the event of a system
contingency. Spinning Reserves may be provided by generating units that
are on-line and loaded at less than maximum output. Given the Southwest
Power Pool, Inc. (SPP) Integrated Marketplace does not extend into the
Western Interconnection, Western Area Power Administration-Upper Great
Plains (Western-UGP) region, as the Balancing Authority, will offer to
provide Spinning Reserves, if available, at the request of SPP as the
Transmission Provider in the WAUW. Operating Reserve-Spinning Reserve
Service in the WAUW will be billed by SPP to the SPP Transmission
Customer along with the associated transmission service provided by
SPP. The SPP Transmission Customer must either purchase this service
from SPP or make alternative comparable arrangements pursuant to the
SPP Tariff to satisfy its Spinning Reserves obligation. Western-UGP's
annual revenue requirement for Spinning Reserves (outlined below) will
be utilized by SPP to calculate the WAUW charges for Spinning Reserves.
Formula Rate
Define
A = U.S. Army Corps of Engineers (Corps) Fixed Charge Rate (%)
B = Corps Generation Net Plant Costs ($)
C = Plant Capacity (kW)
D = Maximum Load in the WAUW (kW)
E = Maximum Generation in the WAUW (kW)
F = Reserve Sharing Program Requirement based upon Load (%)--See Note 1
G = Reserve Sharing Program Requirement based upon Generation (%)--See
Note 2
H = Prior Period True-up
I = Annual cost associated with Western-UGP's current reserve sharing
group membership
Note 1: Currently 3% in the Northwest Power Pool (NWPP) Reserve Sharing
Program
Note 2: Currently 3% in the NWPP Reserve Sharing Program
Spinning Reserves Annual Revenue Requirement = (A * B/C) * ((D * F) +
(E * G)) + H + I
A recalculated revenue requirement will go into effect every
January 1 based on the above formula and updated financial, load/
generation, and Reserve Sharing Program requirements data. Western-UGP
will annually notify SPP and make data and information available to
interested parties for review and comment related to the recalculated
annual revenue requirement on or shortly after September 1 of the
preceding year. Data used and the charges resulting from using this
formula will be posted on the applicable SPP website and Western-UGP's
Open Access Same-Time Information System (OASIS).
If resources are not available from a Western-UGP resource,
Western-UGP, at the request of SPP as the Transmission Provider, will
offer to purchase the Spinning Reserves and pass through the costs,
plus an amount for administration, to SPP for the SPP Transmission
Customer.
In the event that Spinning Reserves are called upon for emergency
use, the SPP Transmission Customer will be assessed a charge for energy
used at the prevailing market energy rate in the WAUW. The prevailing
market energy rate will be based upon a representative hourly energy
index or combination of indexes. The index to be used will be posted on
the applicable SPP website and Western-UGP's OASIS at least 30 days
before use for determining the prevailing market energy rate and will
not be changed more often than once per year unless Western-UGP
determines that the existing index is no longer a reliable price index.
The SPP Transmission Customer would be responsible for providing
transmission service to get the Spinning Reserves to its destination.
Rate Schedule WAUW-AS6, October 1, 2025
(Supersedes Rate Schedule WAUW-AS6 Dated October 1, 2020, Through
September 30, 2025)
United States Department of Energy Western Area Power Administration
Upper Great Plains Region Pick-Sloan Missouri Basin Program--Eastern
Division
Operating Reserve--Supplemental Reserve Service--WAUW
(Approved Under Rate Order No. WAPA-188)
Effective
Beginning on October 1, 2020, and remaining in effect through
September 30, 2025, or until superseded by another rate schedule,
whichever occurs earlier. Notification of the effective date of the
formula rates will be published in the Federal Register. [Note: This
rate schedule was extended by Rate Order No. WAPA-217 through September
30, 2030.]
Applicable
This Rate Schedule applies to the Western Area Power
Administration, Upper Great Plains West Balancing Authority Area
(WAUW). Operating Reserve-Supplemental Reserve Service (Supplemental
Reserves) is needed to serve load in the event of a system contingency;
however, it is not available immediately to serve load but rather
within a short period of time.
Supplemental Reserves may be provided by generating units that are
on-line but unloaded, by quick-start generation, or by interruptible
load. Given the Southwest Power Pool, Inc. (SPP) Integrated Marketplace
does not extend into the Western Interconnection, Western Area Power
Administration-Upper Great Plains (Western-UGP) region, as the
Balancing Authority, will offer to provide Supplemental Reserves, if
available, at the request of SPP as the Transmission Provider, in the
WAUW. Operating Reserve-Supplemental Reserve Service in the WAUW will
be billed by SPP to the SPP Transmission Customer along with the
associated transmission service provided by SPP. The SPP Transmission
Customer must either purchase this service from SPP or make alternative
comparable arrangements pursuant to the SPP Tariff to satisfy its
[[Page 104149]]
Supplemental Reserves obligation. Western-UGP's annual revenue
requirement for Supplemental Reserves (outlined below) will be utilized
by SPP to calculate the WAUW charges for Supplemental Reserves.
Formula Rate
Define
A = U.S. Army Corps of Engineers (Corps) Fixed Charge Rate (%)
B = Corps Generation Net Plant Costs ($)
C = Plant Capacity (kW)
D = Maximum Load in the WAUW (kW)
E = Maximum Generation in the WAUW (kW)
F = Reserve Sharing Program Requirement based upon Load (%)--See Note 1
G = Reserve Sharing Program Requirement based upon Generation (%)--See
Note 2
H = Prior Period True-up
I = Annual cost associated with Western-UGP's current reserve sharing
group membership
Note 1: Currently 3% in the Northwest Power Pool (NWPP) Reserve Sharing
Program
Note 2: Currently 3% in the NWPP Reserve Sharing Program
Supplemental Reserves Annual Revenue Requirement = (A * B/C) * ((D * F)
+ (E * G)) + H + I
A recalculated revenue requirement will go into effect every
January 1 based on the above formula and updated financial, load/
generation, and Reserve Sharing Program requirements data. Western-UGP
will annually notify SPP and make data and information available to
interested parties for review and comment related to the recalculated
annual revenue requirement on or shortly after September 1 of the
preceding year. Data used and the charges resulting from using this
formula will be posted on the applicable SPP website and Western-UGP's
Open Access Same-Time Information System (OASIS).
If resources are not available from a Western-UGP resource,
Western-UGP, at the request of SPP as the Transmission Provider, will
offer to purchase the Supplemental Reserves and pass through the costs,
plus an amount for administration, to SPP for the SPP Transmission
Customer.
In the event Supplemental Reserves are called upon for emergency
use, the SPP Transmission Customer will be assessed a charge for energy
used at the prevailing market energy rate in the WAUW. The prevailing
market energy rate will be based upon a representative hourly energy
index or combination of indexes. The index to be used will be posted on
the applicable SPP website and Western-UGP's OASIS at least 30 days
before use for determining the prevailing market energy rate and will
not be changed more often than once per year unless Western-UGP
determines that the existing index is no longer a reliable price index.
The SPP Transmission Customer would be responsible for providing
transmission service to get the Supplemental Reserves to its
destination.
Rate Schedule WAUW-AS7, October 1, 2025
(Supersedes Rate Schedule WAUW-AS7 Dated October 1, 2020, Through
September 30, 2025)
United States Department of Energy Western Area Power Administration
Upper Great Plains Region Pick-Sloan Missouri Basin Program--Eastern
Division
Generator Imbalance Service--WAUW
(Approved Under Rate Order No. WAPA-188)
Effective
Beginning on October 1, 2020, and remaining in effect through
September 30, 2025, or until superseded by another rate schedule,
whichever occurs earlier. Notification of the effective date of the
formula rates will be published in the Federal Register. [Note: This
rate schedule was extended by Rate Order No. WAPA-217 through September
30, 2030.]
Applicable
This Rate Schedule applies to the Western Area Power
Administration, Upper Great Plains West Balancing Authority Area
(WAUW). Generator Imbalance Service is provided when a difference
occurs between the output of a generator located within Western Area
Power Administration-Upper Great Plains (Western-UGP) region's WAUW and
a delivery schedule from that generator to (1) another Balancing
Authority Area or (2) a load within Western-UGP's WAUW over a single
hour (or different dispatch interval for energy imbalance service
market, if applicable). Given the Southwest Power Pool, Inc. (SPP)
Integrated Marketplace does not extend into the Western
Interconnection, Western-UGP, as the Balancing Authority, will offer to
provide this service at the request of SPP, if it is capable of doing
so, from its own resources or from resources available to it including
possible participation in a Western Interconnection energy imbalance
service market. SPP is the Transmission Provider for the eligible
Western-UGP facilities transferred to the functional control of SPP in
the WAUW. Generator Imbalance Service is needed when transmission
service is provided by SPP and used to deliver energy from a generator
located within the WAUW, or when a difference occurs between the
expected and actual delivery of energy to/from the WAUW over a single
hour (or different dispatch interval for energy imbalance service
market, if applicable) in the event that Western-UGP participates in a
Western Interconnection energy imbalance service market in the WAUW as
the Balancing Authority. Generator Imbalance Service in the WAUW will
be billed by SPP to the SPP Transmission Customer along with the
associated transmission service provided by SPP. The SPP Transmission
Customer must either purchase this service from SPP or make alternative
comparable arrangements pursuant to the SPP Tariff, to satisfy its
Generator Imbalance Service obligation. The SPP Transmission Customer
will incur a charge for either hourly generator imbalances under this
Schedule, WAUW-AS7, or hourly energy imbalances under Rate Schedule
WAUW-AS4 for imbalances occurring during the same hour, but not both,
unless the imbalances aggravate rather than offset each other.
Western-UGP supports the installation of renewable sources of
energy but recognizes that certain operational constraints exist in
managing the significant fluctuations that are a normal part of their
operation. Western-UGP has marketed the maximum practical amount of
power from each of its projects, leaving little or no flexibility for
provision of additional power services. Consequently, Western-UGP will
not regulate for the difference between the output of an intermittent
resource located within the WAUW and a delivery schedule from that
generator serving load located outside of the WAUW. Intermittent
resources serving load outside Western-UGP's WAUW will be required to
be pseudo-tied or dynamically scheduled to another Balancing Authority
Area.
An intermittent resource, for the limited purpose of this Rate
Schedule, is an electric generator that is not dispatchable and cannot
store its fuel source and, therefore, cannot respond to changes in
demand or respond to transmission security constraints.
Formula Rate
(A) In the event that Western-UGP does not participate in a Western
Interconnection energy imbalance
[[Page 104150]]
service market in the WAUW as the Balancing Authority, or such energy
imbalance market is unable to provide the total energy imbalance
requirements for certain loads and generation within the Balancing
Authority Area:
For deviations within +/- 1.5 percent (with a minimum of 2 MW) of
the scheduled transaction to be applied hourly to any generator
imbalance that occurs as a result of the SPP Transmission Customer's
scheduled transaction(s) will be netted on a monthly basis and settled
financially, at the end of the month, at 100 percent of the average
incremental cost.
Deviations greater than +/- 1.5 percent up to 7.5 percent (or
greater than 2 MW up to 10 MW) of the scheduled transaction to be
applied hourly to any generator imbalance that occurs as a result of
the SPP Transmission Customer's scheduled transaction(s) will be
settled financially, at the end of each month. When energy delivered in
a schedule hour from the generation resource is less than the energy
scheduled, the charge is 110 percent of incremental cost. When energy
delivered from the generation resource is greater than the scheduled
amount, the credit is 90 percent of the incremental cost.
Deviations greater than +/- 7.5 percent (or 10 MW) of the scheduled
transaction to be applied hourly to any generator imbalance that occurs
as a result of the SPP Transmission Customer's scheduled transaction(s)
will be settled at 125 percent of Western-UGP's highest incremental
cost for the day when energy delivered in a schedule hour is less than
the energy scheduled or 75 percent of Western-UGP's lowest daily
incremental cost when energy delivered from the generation resource is
greater than the scheduled amount. As an exception, an intermittent
resource will be exempt from this deviation band and will pay the
deviation band charges for all deviations greater than the larger of
1.5 percent or 2 MW.
Deviations from scheduled transactions responding to directives by
the Transmission Provider, a Balancing Authority, or a reliability
coordinator will not be subject to the deviation bands identified above
and, instead, will be settled financially, at the end of the month, at
100 percent of incremental cost. Such directives may include
instructions to correct frequency decay, respond to a reserve sharing
event, or change output to relieve congestion.
Western-UGP's incremental cost will be based upon a representative
hourly energy index or combination of indexes. The index to be used
will be posted on the applicable SPP website and Western-UGP's Open
Access Same-Time Information System (OASIS) at least 30 days before use
for determining the Western-UGP incremental cost and will not be
changed more often than once per year unless Western-UGP determines
that the existing index is no longer a reliable price index.
The pricing and charge for deviations in the deviation bandwidths
is as specified above. Data used and the charges resulting from using
this formula will be posted on the applicable SPP website and Western-
UGP's OASIS.
(B) In the event that Western-UGP participates in a Western
Interconnection energy imbalance service market in the WAUW as the
Balancing Authority:
Charges to the SPP Transmission Customer will reflect only the
pass-through of the applicable charges associated with the Western
Interconnection energy imbalance service market assessed to Western-UGP
as the WAUW Balancing Authority for embedded load and/or generation in
the WAUW of such SPP Transmission Customer that does not make adequate
alternate arrangements in such Western Interconnection energy imbalance
service market or other alternative comparable arrangements pursuant to
the SPP Tariff to satisfy its Generator Imbalance Service obligation.
Western-UGP will post notice on the applicable SPP website and
Western-UGP's OASIS, and also notify existing Transmission Customers,
at least 30 days before Western-UGP participates in a Western
Interconnection energy imbalance service market, as the Balancing
Authority. Western-UGP will also post information related to the
charges assessed by the market operator for Generator Imbalance Service
in the WAUW under such Western Interconnection energy imbalance service
market.
Data used and the charges resulting from using this formula will be
posted on the applicable SPP website and Western-UGP's OASIS.
[FR Doc. 2024-30361 Filed 12-19-24; 8:45 am]
BILLING CODE 6450-01-P