Federal Register / Vol. 89, No. 218 / Tuesday, November 12, 2024 / Notices 88997 

1Rate Order Nos. SWPA–71 (January 1, 2017), 

SWPA–73 (July 15, 2017), SWPA–80 (July 15, 2023) 

2Rate Order Nos. SWPA–72 (September 13, 

2017), SWPA–74 (September 22, 2019), SWPA–77 

(August 30, 2021), SWPA–81 (September 20, 2023). 3See 138 FERC ¶ 62,199 (2012). 

such as orders, notices, and 

rulemakings. 

Public sessions or site visits will be 

posted on the Commission’s calendar 

located at https://www.ferc.gov/newsevents/events along with other related 

information. 

Dated: November 5, 2024. 

Debbie-Anne A. Reese, 

Secretary. 

[FR Doc. 2024–26140 Filed 11–8–24; 8:45 am] 

BILLING CODE 6717–01–P 

DEPARTMENT OF ENERGY 

Southwestern Power Administration 

Integrated System Power Rates 

AGENCY: Southwestern Power 

Administration, DOE. 

ACTION: Notice of proposed rate. 

SUMMARY: Southwestern Power 

Administration (Southwestern) 

proposes to revise the existing 

Integrated System rate schedules to 

meet the identified average annual 

revenue need of $237,821,129, an 

increase of $44,230,649 (22.8 percent), 

effective April 1, 2025, through 

September 30, 2027. Interested persons 

may review the proposed rate and 

supporting studies on Southwestern’s 

website, request to participate in a 

public forum, and submit comments. 

Southwestern will evaluate all 

comments received in this process. 

DATES: A consultation and comment 

period will begin November 12, 2024 

and end February 10, 2025. Written 

comments are due on or before February 

10, 2025. If requested, a public 

information and comment forum 

(Forum) will be held on December 18, 

2024, at 9:00 a.m. to no later than 12:00 

p.m. Central Standard Time (CST). The 

Forum will be conducted via Microsoft 

Teams. Persons desiring to attend the 

Forum should notify Southwestern by 

December 11, 2024, at 11:59 p.m. CST, 

so that a list of Forum participants can 

be prepared. Requests to attend the 

Forum should be sent via email to 

swparates@swpa.gov should include the 

individual’s name, address, phone 

number, entity (if any) they represent, 

and email address. Persons desiring to 

speak at the Forum should specify this 

in their notification to Southwestern; 

others may speak if time permits. 

If Southwestern does not receive a 

request for a Forum, the Forum will not 

be held. If a Forum is requested, the 

Microsoft Teams meeting information 

will be posted to Southwestern’s 

website. 

ADDRESSES: Written comments should 

be submitted to: Fritha Ohlson, Senior 

Vice President, Chief Operating Officer, 

Office of Corporate Operations, 

Southwestern Power Administration, 

U.S. Department of Energy, One West 

Third Street, Tulsa, Oklahoma 74103 or 

emailed to swparates@swpa.gov. 

FOR FURTHER INFORMATION CONTACT: 

Ashley Corker, Director, Division of 

Resources and Rates, Southwestern 

Power Administration, U.S. Department 

of Energy, One West Third Street, Tulsa, 

Oklahoma 74103, (918) 595–6682, 

ashley.corker@swpa.gov. 

SUPPLEMENTARY INFORMATION: 

Southwestern markets power from 24 

multi-purpose reservoir projects with 

hydroelectric power facilities 

constructed and operated by the Corps. 

These projects are located in Arkansas, 

Missouri, Oklahoma, and Texas. 

Southwestern’s marketing area includes 

these states plus Kansas and Louisiana. 

The costs associated with 22 of these 24 

hydropower projects are repaid with 

revenues received under the Integrated 

System rates. These rates also cover the 

costs of Southwestern’s transmission 

facilities that consist of 1,381 miles of 

high-voltage transmission lines, 27 

substations, and 46 microwave and VHF 

radio sites. 

On September 30, 2013, the Deputy 

Secretary of Energy, via Rate Order No. 

SWPA–66, placed Southwestern’s 

Integrated System rate schedules (P–13, 

NFTS–13, and EE–13) into effect until 

September 30, 2017. Subsequently, rate 

schedule NFTS–13 was renamed to 

NFTS–13A and rate schedule P–13 was 

renamed to P–13A and then later to P– 

13B, in each case with no revenue 

adjustment.1 Additionally, all three rate 

schedules have been extended with no 

revenue adjustment.2 Most recently, the 

Southwestern Administrator extended 

rate schedules P–13B, NFTS–13A, and 

EE–13, via Rate Order No. SWPA–85, 

through September 30, 2025. 

The guidelines for preparation of 

power repayment studies are included 

in DOE Order No. RA 6120.2, ‘‘Power 

Marketing Administration Financial 

Reporting.’’ In simple terms, the rate 

process works as follows. First, 

Southwestern conducts a Power 

Repayment Study to determine whether 

its current revenues are sufficient for 

Southwestern to meet its repayment 

obligations. If a revenue shortfall (or 

surplus) is indicated, Southwestern 

conducts a revised Power Repayment 

Study to determine the level of revenue 

needed. If the revenue change needed to 

meet Southwestern’s repayment 

obligations is within a small margin of 

Agency discretion, Southwestern will 

finalize the Power Repayment Studies 

for that year and Southwestern’s rates 

will not be adjusted. This is what 

occurred annually for Southwestern’s 

Integrated System Rates from 2013 until 

2023. 

If, however, Southwestern’s annual 

Power Repayment Studies indicate a 

revenue shortfall (or surplus) outside of 

that small margin of Agency discretion, 

Southwestern must then engage in a 

Rate Design Study to inform the 

Administrator as to what the new 

proposed rates should be in order to 

generate the needed revenue. This is 

what occurred in 2023. 

Unlike previous years, Southwestern’s 

2023 Power Repayment Studies 

indicated the need for a revenue 

increase that was substantial enough to 

impact Southwestern’s ability to meet 

its repayment obligations. The 2023 

Power Repayment Studies indicated the 

need for an increase of $44,230,649 in 

average annual revenue. Southwestern 

then engaged in a Rate Design Study to 

develop rates necessary to generate this 

additional revenue. The resulting rates 

are described in the chart. 

Part of the total additional revenue 

identified by the Power Repayment 

Studies is a need to increase revenues 

specifically for purchased power and 

wheeling. The Purchased Power & 

Wheeling Adder (PPWA) produces 

revenues which are segregated to cover 

the cost of power purchased to meet 

contractual obligations. The PPWA is 

established to reflect revenues required 

to meet Southwestern’s purchased 

power and wheeling needs on an 

average annual basis. The PPWA rate 

will increase to reflect the increasing 

average cost of purchasing power over 

the period as well as the cost of firm 

transmission to wheel power and energy 

from two projects, Blakely Mountain 

and DeGray, from MISO into 

Southwestern’s system. Revenue from 

the sale of excess energy from Blakely 

Mountain and DeGray will offset the 

increase in purchased power and 

wheeling cost. The Administrator’s 

authority to adjust the PPWA at her or 

his discretion with the Purchased Power 

& Wheeling Adder Adjustment 

(PPWAA) will remain in force.3 The 

PPWAA is limited to two adjustments 

per year not to exceed a total of ±8.7 

mills per kilowatt-hour per year. The 

PPWA will increase to $0.0087 per 

kilowatt-hour and the PPWAA will 


khammond on DSKJM1Z7X2PROD with NOTICES
88998 Federal Register / Vol. 89, No. 218 / Tuesday, November 12, 2024 / Notices 

decrease to $0.00 per kilowatt-hour 

when the proposed rate schedules take 

effect. 

Additionally, the Capacity Overrun 

and Energy Overrun penalties in the 

proposed Hydro Peaking Power rate 

schedule have been updated to be 

formula rates, which are the greater of 

the penalties as included in P–13B, or 

the applicable day-ahead locational 

marginal price. This change is to ensure 

that penalties are sufficient to cover the 

financial impact of unauthorized 

capacity and energy overruns. The 

Excess Energy rate schedule has also 

been converted to a formula rate based 

on the applicable market rates at the 

time of sale, rather than a set rate as in 

EE–13. Like EE–13, the proposed Excess 

Energy rate schedule does not include a 

transmission component, as 

transmission service will be the sole 

responsibility of the entity purchasing 

excess energy. 

Below is a comparison of the existing 

and proposed Integrated System rates: 

Existing Proposed Change 

P–13B P–23 Dollars Percent 

Hydro Peaking Power 

Energy: 

Peaking Energy ................................................................. $0.0094 /kWh ................ $0.0128 /kWh ................ $0.0034 36.2 

Supplemental Peaking Energy .......................................... $0.0094 /kWh ................ $0.0128 /kWh ................ 0.0034 36.2 

Purchased Power & Wheeling .......................................... $0.0059 /kWh ................ $0.0087 /kWh ................ 0.0028 47.5 

Administrator’s Discretionary Adder Adjustment—Annual 

Limit.

+/¥$0.0059 /kWh ......... +/¥$0.0087 /kWh ......... 0.0028 47.5 

Capacity: 

Grid or 138–161 kV ........................................................... $4.50 /kW/Mo ................ $5.30 /kW/Mo ................ 0.80 17.8 

Regulation & Frequency Response .................................. $0.07 /kW/Mo ................ $0.0208 /kW/Mo ............ (0.0492) ¥70.3 

Operational Reserves—Spinning ...................................... $0.0146 /kW/Mo ............ $0.0208 /kW/Mo ............ 0.0062 42.5 

Operational Reserves—Supplemental .............................. $0.0146 /kW/Mo ............ $0.0208 /kW/Mo ............ 0.0062 42.5 

Energy Imbalance ............................................................. $0.0 /kW/Mo .................. $0.0 /kW/Mo .................. 0.0 0.0 

Regulation Purchased Adder (load within SWPA BAA) ... prorated share of total 

energy cost.

prorated share of total 

energy cost.

N/A N/A 

Transformation Service 69 kV & less (applied to usage, 

not reservation).

$0.46 /kW/Mo ................ $0.86 /kW/Mo ................ 0.4000 87.0 

Non-Federal Transmission & Interconnection Facilities Service 

NFTS–13A NFS–23 Dollars Percent 

Firm Point-to-Point Capacity .................................................... $1.48 /kW/Mo ................ $1.15 /kW/Mo ................ ($0.33) ¥22.3 

Non-Firm Point-to-Point Capacity (80 percent of Firm Pointto-Point).$1.184 /kW/Mo .............. $0.92 /kW/Mo ................ (0.26) ¥22.3 

Network Integration .................................................................. $1.48 /kW/Mo ................ $1.15 /kW/Mo ................ (0.33) ¥22.3 

Interconnection Facilities .......................................................... $1.48 /kW/Mo ................ $1.15 /kW/Mo ................ (0.33) ¥22.3 

Transformation Service 69 kV & less (applied to usage, not 

reservation).

$0.46 /kW/Mo ................ $0.86 /kW/Mo ................ 0.40 87.0 

Scheduling, System Control, & Dispatch ................................. $0.09 /kW/Mo ................ $0.17 /kW/Mo ................ 0.08 88.9 

Reactive Supply & Voltage Control .......................................... $0.04 /kW/Mo ................ $0.10 /kW/Mo ................ 0.06 150.0 

Regulation & Frequency Response ......................................... $0.07 /kW/Mo ................ $0.0208 /kW/Mo ............ (0.0492) ¥70.3 

Operational Reserves—Spinning ............................................. $0.0146 /kW/Mo ............ $0.0208 /kW/Mo ............ 0.0062 42.5 

Operational Reserves—Supplemental ..................................... $0.0146 /kW/Mo ............ $0.0208 /kW/Mo ............ 0.0062 42.5 

Energy Imbalance ..................................................................... $0.0 /kW/Mo .................. $0.0 /kW/Mo .................. 0.0 0.0 

Regulation Purchased Adder (load within SWPA BAA) .......... prorated share of total 

energy cost.

prorated share of total 

energy cost.

N/A N/A 

Excess Energy 

EE–13 EE–23 Dollars Percent 

Excess Energy .......................................................................... $0.0094 /kWh ................ formula rate ................... N/A N/A 

Public Participation 

The procedures for public 

participation are found at title 10, part 

903, subpart A of the Code of Federal 

Regulations (10 CFR part 903). This 

proposed action is considered a ‘‘Major 

Rate Adjustment,’’ as defined by 10 CFR 

903.2(d). As such, in accordance with 

10 CFR 903.14, the public consultation 

and comment period is 90 days. In 

accordance with 10 CFR 903.15(a) and 

903.16(a), Southwestern will hold a 

Forum for this proposed rate adjustment 

if requested. Southwestern will review 

and consider all timely public 

comments at the conclusion of the 

consultation and comment period and 

adjust the proposal as appropriate. The 

Integrated System rate schedules will 

then be approved on an interim basis. 

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 Southwestern’s 

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 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 


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I 
Federal Register / Vol. 89, No. 218 / Tuesday, November 12, 2024 / Notices 88999 

4 In compliance with the National Environmental 

Policy Act (NEPA) of 1969, as amended, 42 U.S.C. 

4321 through 4347; the Council on Environmental 

Quality Regulations for implementing NEPA (40 

CFR parts 1500 through 1508); and DOE NEPA 

Implementing Procedures and Guidelines (10 CFR 

part 1021) 

Under Secretary for Infrastructure. By 

Redelegation Order No. S3–DEL– 

SWPA1–2023, effective April 10, 2023, 

the Under Secretary for Infrastructure 

redelegated the authority to confirm, 

approve, and place such rates into effect 

on an interim basis to the 

Administrator, Southwestern. 

Availability of Information 

The 2023 Integrated System Power 

Repayment Studies and the associated 

Rate Design Study as well as the 

proposed Integrated System rate 

schedules are available on 

Southwestern’s website at: https://

www.energy.gov/swpa/rate-scheduleactions. At the conclusion of the 

consultation and comment period, 

Southwestern will post all comments 

received at the same website location. If 

a Forum is held, the transcript of the 

Forum and any other documents 

introduced during the Forum will also 

be made available on Southwestern’s 

website. 

Environmental Impact 

Southwestern is in the process of 

determining whether an environmental 

assessment or an environmental impact 

statement should be prepared or if this 

action can be categorically excluded 

from those requirements.4

Determination Under Executive Order 

12866 

Southwestern 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. 

Signing Authority 

This document of the Department of 

Energy was signed on November 6, 

2024, by Mike Wech, Administrator for 

Southwestern 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 

DOE. This administrative process in no 

way alters the legal effect of this 

document upon publication in the 

Federal Register. 

Signed in Washington, DC, on November 6, 

2024. 

Treena V. Garrett, 

Federal Register Liaison Officer, U.S. 

Department of Energy. 

[FR Doc. 2024–26144 Filed 11–8–24; 8:45 am] 

BILLING CODE 6450–01–P 

DEPARTMENT OF ENERGY 

Western Area Power Administration 

Final 2028 Parker-Davis Project Power 

Marketing Plan and Call for Resource 

Pool Applications 

AGENCY: Western Area Power 

Administration, Department of Energy 

(DOE). 

ACTION: Notice of final plan and call for 

resource pool applications. 

SUMMARY: The Department of Energy 

(DOE), Western Area Power 

Administration (WAPA), Desert 

Southwest Region (DSW), announces its 

Final 2028 Parker-Davis Project (P–DP) 

Power Marketing Plan (Final 2028 Plan) 

and issues a Call for Resource Pool 

Applications. This notice responds to 

comments received on the Proposed 

2028 P–DP Power Marketing Plan 

(Proposed 2028 Plan). The Final 2028 

Plan specifies the terms and conditions 

under which WAPA will market power 

from P–DP from October 1, 2028, 

through September 30, 2048. WAPA 

will offer new contracts for the sale of 

power to existing contractors and create 

a resource pool for potential new 

applicants. Entities who wish to apply 

for a new allocation of power from 

WAPA, and who meet the criteria 

defined in the Final 2028 Plan, must 

submit a formal application using the 

Applicant Profile Data (APD) form and 

must meet the Eligibility Criteria and 

Allocation Criteria described herein. 

The General Criteria and Contract 

Principles set forth in the Final 2028 

Plan will apply to new allottees and 

existing contractors. This Final 2028 

Plan supersedes all previous marketing 

plans for P–DP. 

DATES: The Final 2028 Plan will become 

effective December 12, 2024 to make 

power allocations and complete the 

other processes necessary to begin 

providing service on October 1, 2028. 

Resource pool applications must be 

received on or before 5:00 p.m., 

Mountain Standard Time (MST), on 

January 31, 2025. WAPA will accept 

applications using the APD form by 

email or by certified mail (or its 

equivalent). Applications sent by 

regular mail will be accepted if 

postmarked before January 31, 2025, 

and received no later than February 5, 

2025. WAPA will not consider 

applications unless they are received by 

the prescribed dates. 

ADDRESSES: Preference entities 

interested in applying for an allocation 

of WAPA power may complete the APD 

form available at https://www.wapa.gov/ 

about-wapa/regions/dsw/ 

pdpremarketing/ and mail the signed 

and dated APD form to Ms. Jennifer 

Henn, Power Marketing Advisor, Desert 

Southwest Region, Western Area Power 

Administration, P.O. Box 6457, 

Phoenix, AZ 85005–6457. APD 

application forms with an electronic 

signature (e-signature) may be emailed 

to pdp-remarketing@wapa.gov. If an 

electronic signature is not available, the 

signed APD form may be scanned and 

emailed to the address above, faxed to 

(602) 605–4663, or mailed it to the 

address above. All APD forms must be 

received by WAPA within the time 

required in the DATES section, herein. 

WAPA will publish a notice of Proposed 

2028 Allocations in the Federal Register 

after evaluating all applications. 

FOR FURTHER INFORMATION CONTACT: 

Jennifer Henn, Power Marketing 

Advisor, Desert Southwest Region, 

Western Area Power Administration, 

(602) 605–2572 or email: pdpremarketing@wapa.gov. Information on 

development of the Final 2028 Plan can 

be found at https://www.wapa.gov/ 

about-wapa/regions/dsw/ 

pdpremarketing/. 

SUPPLEMENTARY INFORMATION: 

Development of the Final 2028 Plan 

P–DP power facilities include Davis 

Dam, with its current total operating 

capacity of 255,000 kilowatts (kW) for 

P–DP and expected increase of 

approximately 3,750 kW from the 

rewind of Unit 3, and Parker Dam, with 

60,000 kW of operating capacity allotted 

to P–DP and 60,000 kW allotted to 

Metropolitan Water District of Southern 

California. Both dams are owned and 

operated by the Bureau of Reclamation 

(Reclamation). WAPA owns and 

operates approximately 1,500 miles of 

high voltage transmission lines and 45 

substations throughout Arizona, 

California, and Nevada to facilitate 

delivery of P–DP power in those three 

states. 

On September 30, 2028, WAPA’s 

existing long-term sales contracts for P– 

DP power will expire. WAPA began 

developing the Final 2028 Plan with a 

series of informal public information 

meetings for existing and new potential 

contractors. These meetings helped 


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