Federal Register / Vol. 89, No. 245 / Friday, December 20, 2024 / Notices 104143 

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 

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 http://

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 

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 

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 


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1 50 FR 37835 (Sept. 18, 1985) and 84 FR 5347 

(Feb. 21, 2019). 

1This 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. 

2 50 FR 37835 (Sept. 18, 1985) and 84 FR 5347 

(Feb. 21, 2019). 

3Order 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). 

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 

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 

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 


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5The 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). 

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. 

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 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. 

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. 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 

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 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 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) 

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 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. 


ddrumheller on DSK120RN23PROD with NOTICES1
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.] 

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. 

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 


ddrumheller on DSK120RN23PROD with NOTICES1
Federal Register / Vol. 89, No. 245 / Friday, December 20, 2024 / Notices 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, 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 


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. 

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. 

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 


ddrumheller on DSK120RN23PROD with NOTICES1