Federal Register / Vol. 86, No. 175 / Tuesday, September 14, 2021 / Notices 51141 

DEPARTMENT OF ENERGY 

Federal Energy Regulatory 

Commission 

[Docket No. ER21–2826–000] 

NRG Curtailment Solutions, Inc.; 

Supplemental Notice That Initial 

Market-Based Rate Filing Includes 

Request for Blanket Section 204 

Authorization 

This is a supplemental notice in the 

above-referenced proceeding of NRG 

Curtailment Solutions, Inc.’s application 

for market-based rate authority, with an 

accompanying rate tariff, noting that 

such application includes a request for 

blanket authorization, under 18 CFR 

part 34, of future issuances of securities 

and assumptions of liability. 

Any person desiring to intervene or to 

protest should file with the Federal 

Energy Regulatory Commission, 888 

First Street NE, Washington, DC 20426, 

in accordance with Rules 211 and 214 

of the Commission’s Rules of Practice 

and Procedure (18 CFR 385.211 and 

385.214). Anyone filing a motion to 

intervene, or protest must serve a copy 

of that document on the Applicant. 

Notice is hereby given that the 

deadline for filing protests with regard 

to the applicant’s request for blanket 

authorization, under 18 CFR part 34, of 

future issuances of securities and 

assumptions of liability, is September 

27, 2021. 

The Commission encourages 

electronic submission of protests and 

interventions in lieu of paper, using the 

FERC Online links at http://

www.ferc.gov. To facilitate electronic 

service, persons with internet access 

who will eFile a document and/or be 

listed as a contact for an intervenor 

must create and validate an 

eRegistration account using the 

eRegistration link. Select the eFiling 

link to log on and submit the 

intervention or protests. 

Persons unable to file electronically 

may mail similar pleadings to the 

Federal Energy Regulatory Commission, 

888 First Street NE, Washington, DC 

20426. Hand delivered submissions in 

docketed proceedings should be 

delivered to Health and Human 

Services, 12225 Wilkins Avenue, 

Rockville, Maryland 20852. 

In addition to publishing the full text 

of this document in the Federal 

Register, the Commission provides all 

interested persons an opportunity to 

view and/or print the contents of this 

document via the internet through the 

Commission’s Home Page (http://

www.ferc.gov) using the ‘‘eLibrary’’ link. 

Enter the docket number excluding the 

last three digits in the docket number 

field to access the document. At this 

time, the Commission has suspended 

access to the Commission’s Public 

Reference Room, due to the 

proclamation declaring a National 

Emergency concerning the Novel 

Coronavirus Disease (COVID–19), issued 

by the President on March 13, 2020. For 

assistance, contact the Federal Energy 

Regulatory Commission at 

FERCOnlineSupport@ferc.gov or call 

toll-free, (886) 208–3676 or TYY, (202) 

502–8659. 

Dated: September 7, 2021. 

Debbie-Anne A. Reese, 

Deputy Secretary. 

[FR Doc. 2021–19743 Filed 9–13–21; 8:45 am] 

BILLING CODE 6717–01–P 

DEPARTMENT OF ENERGY 

Southwestern Power Administration 

Integrated System Rate Schedules 

AGENCY: Southwestern Power 

Administration, DOE. 

ACTION: Notice of extension of integrated 

system rate schedules. 

SUMMARY: The Administrator, 

Southwestern Power Administration 

(Southwestern) has approved and 

placed into effect on an interim basis 

Rate Order No. SWPA–77, which 

extends the following existing 

Southwestern Integrated System rate 

schedules: Rate Schedule P–13A, 

Wholesale Rates for Hydro Peaking 

Power; Rate Schedule NFTS–13A, 

Wholesale Rates for Non-Federal 

Transmission/Interconnection Facilities 

Service; and Rate Schedule EE–13, 

Wholesale Rates for Excess Energy. This 

is an interim rate action effective 

October 1, 2021, extending for a period 

of two years through September 30, 

2023. 

DATES: The effective period for the rate 

schedules specified in Rate Order No. 

SWPA–77 is October 1, 2021, through 

September 30, 2023. 

FOR FURTHER INFORMATION CONTACT: Ms. 

Fritha Ohlson, Senior Vice President 

and Chief Operating Officer, Office of 

Corporate Operations, Southwestern 

Power Administration, U.S. Department 

of Energy, One West Third Street, Tulsa, 

Oklahoma 74103, (918) 595–6684 or 

email: fritha.ohlson@swpa.gov. 

SUPPLEMENTARY INFORMATION: Rate Order 

No. SWPA–77 is approved and placed 

into effect on an interim basis for the 

period October 1, 2021, through 

September 30, 2023, for the following 

Southwestern Integrated System rate 

schedules: 

Rate Schedule P–13A, Wholesale Rates 

for Hydro Peaking Power 

Rate Schedule NFTS–13A, Wholesale 

Rates for Non-Federal Transmission/ 

Interconnection Facilities Service 

Rate Schedule EE–13, Wholesale Rates 

for Excess Energy 

Decision Rationale 

The Southwestern Administrator 

completed an annual review of the 

continuing adequacy of the existing rate 

schedules for the Integrated System. 

This review, as presented in the 2021 

Integrated System Power Repayment 

Studies (PRSs), indicated the need for a 

1.3 percent revenue increase to continue 

to satisfy cost recovery criteria. It is 

Southwestern practice for the 

Administrator to defer, on a case-bycase basis, revenue adjustments for the 

Integrated System if such adjustments 

are within plus or minus two percent of 

the revenue estimate based on the 

current Integrated System rate 

schedules. The deferral of a revenue 

adjustment (rate change) provides for 

rate stability and savings on the 

administrative costs of implementation. 

The Administrator determined it to be 

prudent to defer the increase and allow 

the current Integrated System rate 

schedules, which are set to expire 

September 30, 2021, to remain in effect. 

To ensure that Southwestern has rate 

schedules in effect for collection of 

revenue in order to meet its repayment 

obligations, the Administrator has 

approved and placed into effect a twoyear extension of the Integrated System 

rate schedules for the period October 1, 

2021, through September 30, 2023. 

The Administrator followed part 903, 

subpart A of title 10 of the Code of 

Federal Regulations (CFR), ‘‘Procedures 

for Public Participation in Power and 

Transmission Rate Adjustments and 

Extensions’’ for the extension of the rate 

schedules. The public was informed by 

notice, published in the Federal 

Register (86 FR 31500 (June 14, 2021)) 

of the proposed extension of the rate 

schedules and of the opportunity to 

provide written comments for a period 

of 30 days ending July 14, 2021. No 

comments were received. 


tkelley on DSK125TN23PROD with NOTICES
51142 Federal Register / Vol. 86, No. 175 / Tuesday, September 14, 2021 / Notices 

Legal Authority 

By Delegation Order No. 00–037.00B, 

effective November 19, 2016, the 

Secretary of Energy delegated: (1) The 

authority to develop power and 

transmission rates to the Southwestern 

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–S4– 

2021, effective February 25, 2021, the 

Acting Secretary of Energy also 

delegated the authority to confirm, 

approve, and place such rates into effect 

on an interim basis to the Under 

Secretary for Science (and Energy). By 

Redelegation Order No. S4–DEL–OE1– 

2021, effective March 25, 2021, the 

Acting Under Secretary for Science (and 

Energy) redelegated the authority to 

confirm, approve, and place such rates 

into effect on an interim basis to the 

Assistant Secretary for Electricity. And 

by Redelegation Order No. 00–002.10– 

04, effective July 8, 2020, the Assistant 

Secretary for Electricity further 

redelegated the authority to confirm, 

approve, and place such rates into effect 

on an interim basis to the Southwestern 

Administrator. This redelegation order, 

despite predating the February 2021 

delegation and March 2021 

redelegation, remains valid. By these 

delegations, and in accordance with 10 

CFR 903.22(h) and 10 CFR 903.23(a), as 

amended, (84 FR 5347, 5350 (Feb. 21, 

2019)), the Administrator may approve 

and extend, on an interim basis, rates 

previously confirmed and approved by 

FERC beyond the period specified by 

FERC. 

Environmental Impact 

Southwestern previously determined 

that the rate change actions, placed into 

effect on October 1, 2013 for the 

Integrated System fit within the class of 

categorically excluded actions as listed 

in appendix B to subpart D of 10 CFR 

part 1021, the Implementing Procedures 

and Guidelines of the National 

Environmental Policy Act of 1969, as 

amended (42 U.S.C. 4321–4347), 

categorical exclusions applicable to 

B4.3: Electric power marketing rate 

changes, which does not require 

preparation of either an environmental 

impact statement (EIS) or an 

environmental assessment (EA). On May 

27, 2021, Southwestern determined that 

categorical exclusion B4.3 applies to the 

current action. 

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. 

UNITED STATES OF AMERICA 

DEPARTMENT OF ENERGY 

ADMINISTRATOR, SOUTHWESTERN 

POWER ADMINISTRATION 

In the matter of: Southwestern Power 

Administration Integrated System 

Rate Schedules 

Rate Order No. SWPA–77 

ORDER APPROVING EXTENSION OF 

RATE SCHEDULES ON AN INTERIM 

BASIS 

(August 30, 2021) 

Pursuant to Sections 301(b) and 

302(a) and of the Department of Energy 

Organization Act, Public Law 42 U.S.C. 

7151(b) and 7152(a), the functions of the 

Secretary of the Interior and the Federal 

Power Commission under Section 5 of 

the Flood Control Act of 1944, 16 U.S.C. 

825s, relating to the Southwestern 

Power Administration (Southwestern), 

were transferred to, and vested in the 

Secretary of Energy. By Delegation 

Order No. 00–037.00B, effective 

November 19, 2016, the Secretary of 

Energy delegated: (1) The authority to 

develop power and transmission rates to 

the Southwestern 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–S4–2021, effective 

February 25, 2021, the Acting Secretary 

of Energy also delegated the authority to 

confirm, approve, and place such rates 

into effect on an interim basis to the 

Under Secretary for Science (and 

Energy). By Redelegation Order No. S4– 

DEL–OE1–2021, effective March 25, 

2021, the Acting Under Secretary for 

Science (and Energy) redelegated the 

authority to confirm, approve, and place 

such rates into effect on an interim basis 

to the Assistant Secretary for Electricity. 

And by Redelegation Order No. 00– 

002.10–04, effective July 8, 2020, the 

Assistant Secretary for Electricity 

further redelegated the authority to 

confirm, approve, and place such rates 

into effect on an interim basis to the 

Southwestern Administrator. This 

redelegation order, despite predating the 

February 2021 delegation and March 

2021 redelegation, remains valid. By 

these delegations, and in accordance 

with 10 CFR 903.22(h) and 10 CFR 

903.23(a), as amended, (84 FR 5347, 

5350 (Feb. 21, 2019)), the Southwestern 

Administrator may approve and extend, 

on an interim basis, rates previously 

confirmed and approved by FERC 

beyond the period specified by FERC. 

Pursuant to that delegated authority, the 

Southwestern Administrator has issued 

this interim rate order. 

BACKGROUND 

The following rate schedules for the 

Integrated System were confirmed and 

approved on a final basis by FERC on 

January 9, 2014, in Docket No. EF14–1– 

000 (146 FERC ¶ 62,016) for the period 

October 1, 2013, through September 30, 

2017: 

Rate Schedule P–13, Wholesale Rates 

for Hydro Peaking Power 

Rate Schedule NFTS–13, Wholesale 

Rates for Non-Federal Transmission/ 

Interconnection Facilities Service 

Rate Schedule EE–13, Wholesale Rates 

for Excess Energy 

Since initial FERC approval, 

Southwestern added a new section 

within rate schedule NFTS–13 with no 

revenue adjustment and the revised rate 

schedule was designated NFTS–13A to 

reflect the change. The following rate 

schedule was placed into effect on an 

interim basis by the Deputy Secretary 

for Energy, effective January 1, 2017, 

and was confirmed and approved on a 

final basis by FERC on March 9, 2017, 

in Docket No. EF14–1–001 (158 FERC 

¶ 62,182): 

Rate Schedule NFTS–13A, Wholesale 

Rates for Non-Federal Transmission/ 

Interconnection Facilities Service 

A two-year extension of all Integrated 

System rate schedules was approved on 

an interim basis by the Deputy Secretary 

in Docket No. EF14–1–002 for the 

period October 1, 2017, through 

September 30, 2019. Subsequently, 

Southwestern added a new section 

within rate schedule P–13 with no 

revenue adjustment and the revised rate 

schedule was designated P–13A to 

reflect the change. The following rate 

schedule was placed into effect on an 

interim basis by the Assistant Secretary 

for Electricity, effective July 1, 2019, 

and was confirmed and approved on a 

final basis by FERC on August 29, 2019, 

in Docket No. EF14–1–003 (168 FERC 

¶ 62,125): 

Rate Schedule P–13A, Wholesale Rates 

for Hydro Peaking Power 

A two-year extension of all Integrated 

System rate schedules was approved on 

an interim basis by the Assistant 

Secretary for Electricity for the period of 


tkelley on DSK125TN23PROD with NOTICES
Federal Register / Vol. 86, No. 175 / Tuesday, September 14, 2021 / Notices 51143 

1Supersedes Rate Schedule P–13. 

** Extended through September 30, 2023, by 

approval of Rate Order No. SWPA–77 by the 

Administrator, Southwestern Power 

Administration. 

October 1, 2019, through September 30, 

2021. 

DISCUSSION 

The existing Integrated System rate 

schedules are based on the 

Southwestern 2013 Power Repayment 

Studies (PRSs). PRSs have been 

completed for the Integrated System 

each year since approval of the existing 

rate schedules. Since 2013, subsequent 

PRSs have indicated the need for a 

minimal rate increase, all within the 

plus or minus two percent rate 

adjustment threshold practice 

established by the Administrator on 

June 23, 1987. Therefore, the 

Administrator deferred these rate 

adjustments in the best interest of the 

government. 

However, the existing rate schedules 

are set to expire on September 30, 2021. 

Consequently, Southwestern proposed 

to extend the existing rate schedules for 

a two-year period ending September 30, 

2023, on an interim basis under the 

implementation authorities noted in 10 

CFR 903.22(h) and 10 CFR 903.23(a). 

Southwestern followed 10 CFR part 

903, ‘‘Procedures for Public 

Participation in Power and 

Transmission Rate Adjustments and 

Extensions,’’ for the proposed extension 

of the rate schedules. An opportunity 

for customers and other interested 

members of the public to review and 

comment on the proposed extension of 

the rate schedules was announced by 

notice, published in the Federal 

Register on June 14, 2021 (86 FR 31500), 

with written comments due by July 14, 

2021. 

COMMENTS AND RESPONSES 

Southwestern received no comments 

regarding the extension of the rate 

schedules. 

AVAILABILITY OF INFORMATION 

Information regarding the extension of 

the rate schedules is available for public 

review in the offices of Southwestern 

Power Administration, Williams Tower 

I, One West Third Street, Tulsa, 

Oklahoma 74103. The rate schedules are 

available on the Southwestern website 

at www.swpa.gov. 

ADMINISTRATION’S CERTIFICATION 

The 2013 Integrated System PRSs 

indicated that the current rate schedules 

will repay all costs of the Integrated 

System, including amortization of the 

power investment consistent with the 

provisions of Department of Energy 

Order No. RA 6120.2. The 2021 

Integrated System PRSs indicated the 

need for an annual revenue increase of 

1.3 percent. However, the 2021 rate 

adjustment falls within the 

Southwestern established plus or minus 

two percent Integrated System rate 

adjustment threshold practice and was 

deferred. 

The Southwestern 2022 PRSs will 

determine the appropriate level of 

revenues needed for the next rate 

period. In accordance with Delegation 

Order No. 00–037.00B, effective 

November 19, 2016, and Section 5 of the 

Flood Control Act of 1944, the 

Administrator has determined that the 

existing rate schedules are the lowest 

possible rates consistent with sound 

business principles, and their extension 

is consistent with applicable law. 

ENVIRONMENT 

Southwestern previously determined 

that the rate change actions, placed into 

effect on October 1, 2013 for the 

Integrated System, fit within the class of 

categorically excluded actions as listed 

in appendix B to subpart D of 10 CFR 

part 1021, the Implementing Procedures 

and Guidelines of the National 

Environmental Policy Act of 1969, as 

amended (42 U.S.C. 4321–4347), 

categorical exclusions applicable to 

B4.3: Electric power marketing rate 

changes, which does not require 

preparation of either an environmental 

impact statement (EIS) or an 

environmental assessment (EA). On May 

27, 2021, Southwestern determined that 

categorical exclusion B4.3 applies to the 

current action. 

ADMINISTRATIVE PROCEDURES 

Under the Administrative Procedure 

Act (5 U.S.C. 553(d)), publication or 

service of a substantive rule must be 

made not less than 30 days before its 

effective date, except (1) a substantive 

rule that grants or recognizes an 

exemption or relieves a restriction; (2) 

interpretative rules and statements of 

policy; or (3) as otherwise provided by 

the agency for good cause found and 

published with the rule. The 

Administrator finds good cause to waive 

the 30-day delay in the effective date of 

this action as unnecessary for the 

following reasons: (1) This is an 

extension of rates previously approved 

by FERC, pursuant to 10 CFR 903.23(a); 

(2) there are no substantive changes, as 

the existing rate schedules and 

anticipated revenues remain the same; 

and (3) the Administrator provided 

notice and opportunity for public 

comment more than 30 days prior to the 

effective date of the rate extension and 

received no comments. 

ORDER 

In view of the foregoing, and pursuant 

to delegated authority from the 

Secretary of Energy, I hereby extend on 

an interim basis, for the period of two 

years, effective October 1, 2021, through 

September 30, 2023, the current 

Integrated System rate schedules: 

Rate Schedule P–13A, Wholesale Rates 

for Hydro Peaking Power 

Rate Schedule NFTS–13A, Wholesale 

Rates for Non-Federal Transmission/ 

Interconnection Facilities Service 

Rate Schedule EE–13, Wholesale Rates 

for Excess Energy 

Signing Authority 

This document of the Department of 

Energy was signed on August 30, 2021, 

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 September 

8, 2021. 

Treena V. Garrett, 

Federal Register Liaison Officer, U.S. 

Department of Energy. 

UNITED STATES DEPARTMENT OF 

ENERGY 

SOUTHWESTERN POWER 

ADMINISTRATION 

RATE SCHEDULE P–13A 1 ** 

WHOLESALE RATES FOR HYDRO 

PEAKING POWER 

Effective: During the period October 1, 

2013, through September 30, 2023,** in 

accordance with the Federal Energy 

Regulatory Commission (FERC) order 

issued in Docket No. EF14–1–000 (Jan. 

9, 2014), extension approved by the 

Deputy Secretary in Docket No. EF14– 

1–002 (Sept. 13, 2017), modification 

approved by FERC in Docket No. EF14– 

1–003 (Aug. 29, 2019), extension 

approved by Assistant Secretary for 

Electricity in Rate Order No. 74 (Sept. 

22, 2019), and extension approved by 

the Administrator in Rate Order No. 77 

(August 30, 2021). 


tkelley on DSK125TN23PROD with NOTICES
51144 Federal Register / Vol. 86, No. 175 / Tuesday, September 14, 2021 / Notices 

Available: In the marketing area of 

Southwestern Power Administration 

(Southwestern), described generally as 

the States of Arkansas, Kansas, 

Louisiana, Missouri, Oklahoma, and 

Texas. 

Applicable: To wholesale Customers 

which have contractual rights from 

Southwestern to purchase Hydro 

Peaking Power and associated energy 

(Peaking Energy and Supplemental 

Peaking Energy). 

Character and Conditions of Service: 

Three-phase, alternating current, 

delivered at approximately 60 Hertz, at 

the nominal voltage(s), at the point(s) of 

delivery, and in such quantities as are 

specified by contract. 

1. Definitions of Terms 

1.1. Ancillary Services 

The services necessary to support the 

transmission of capacity and energy 

from resources to loads while 

maintaining reliable operation of the 

System of Southwestern in accordance 

with good utility practice, which 

include the following: 

1.1.1. Scheduling, System Control, and 

Dispatch Service 

is provided by Southwestern as 

Balancing Authority Area operator and 

is in regard to interchange and loadmatch scheduling and related system 

control and dispatch functions. 

1.1.2. Reactive Supply and Voltage 

Control From Generation Sources 

Service 

is provided at transmission facilities in 

the System of Southwestern to produce 

or absorb reactive power and to 

maintain transmission voltages within 

specific limits. 

1.1.3. Regulation and Frequency 

Response Service 

is the continuous balancing of 

generation and interchange resources 

accomplished by raising or lowering the 

output of on-line generation as 

necessary to follow the moment-bymoment changes in load and to 

maintain frequency within a Balancing 

Authority Area. 

1.1.4. Spinning Operating Reserve 

Service 

maintains generating units on-line, but 

loaded at less than maximum output, 

which may be used to service load 

immediately when disturbance 

conditions are experienced due to a 

sudden loss of generation or load. 

1.1.5. Supplemental Operating Reserve 

Service 

provides an additional amount of 

operating reserve sufficient to reduce 

Area Control Error to zero within 10 

minutes following loss of generating 

capacity which would result from the 

most severe single contingency. 

1.1.6. Energy Imbalance Service 

corrects for differences over a period of 

time between schedules and actual 

hourly deliveries of energy to a load. 

Energy delivered or received within the 

authorized bandwidth for this service is 

accounted for as an inadvertent flow 

and is returned to the providing party 

by the receiving party in accordance 

with standard utility practice or a 

contractual arrangement between the 

parties. 

1.2. Customer 

The entity which is utilizing and/or 

purchasing Federal Power and Federal 

Energy and services from Southwestern 

pursuant to this Rate Schedule. 

1.3. Demand Period 

The period of time used to determine 

maximum integrated rates of delivery 

for the purpose of power accounting 

which is the 60-minute period that 

begins with the change of hour. 

1.4. Federal Power and Energy 

The power and energy provided from 

the System of Southwestern. 

1.5. Hydro Peaking Power 

The Federal Power that Southwestern 

sells and makes available to the 

Customers through their respective 

Power Sales Contracts in accordance 

with this Rate Schedule. 

1.6. Peaking Billing Demand 

The quantity equal to the Peaking 

Contract Demand for any month unless 

otherwise provided by the Customer’s 

Power Sales Contract. 

1.7. Peaking Contract Demand 

The maximum rate in kilowatts at 

which Southwestern is obligated to 

deliver Federal Energy associated with 

Hydro Peaking Power as set forth in the 

Customer’s Power Sales Contract. 

1.8. Peaking Energy 

The Federal Energy associated with 

Hydro Peaking Power that Southwestern 

sells and makes available to the 

Customer in accordance with the terms 

and conditions of the Customer’s Power 

Sales Contract. 

1.9. Peaking Energy Schedule 

Submission Time 

The time by which Southwestern 

requires the Customer to submit Peaking 

Energy schedules to Southwestern as 

provided for in this Rate Schedule and 

in accordance with the terms and 

conditions of the Customer’s Power 

Sales Contract. 

1.10. Power Sales Contract 

The Customer’s contract with 

Southwestern for the sale of Federal 

Power and Federal Energy. 

1.11. Supplemental Peaking Energy 

The Federal Energy associated with 

Hydro Peaking Power that Southwestern 

sells and makes available to the 

Customer if determined by 

Southwestern to be available and that is 

in addition to the quantity of Peaking 

Energy purchased by the Customer in 

accordance with the terms and 

conditions of the Customer’s Power 

Sales Contract. 

1.12. System of Southwestern 

The transmission and related facilities 

owned by Southwestern, and/or the 

generation, transmission, and related 

facilities owned by others, the capacity 

of which, by contract, is available to and 

utilized by Southwestern to satisfy its 

contractual obligations to the Customer. 

1.13. Uncontrollable Force 

Any force which is not within the 

control of the party affected, including, 

but not limited to failure of water 

supply, failure of facilities, flood, 

earthquake, storm, lightning, fire, 

epidemic, riot, civil disturbance, labor 

disturbance, sabotage, war, act of war, 

terrorist acts, or restraint by court of 

general jurisdiction, which by exercise 

of due diligence and foresight such 

party could not reasonably have been 

expected to avoid. 

2. Wholesale Rates, Terms, and 

Conditions for Hydro Peaking Power, 

Peaking Energy, Supplemental Peaking 

Energy, and Associated Services 

Unless otherwise specified, this 

Section 2 is applicable to all sales under 

the Customer’s Power Sales Contract. 

2.1. Hydro Peaking Power Rates, Terms, 

and Conditions 

2.1.1. Monthly Capacity Charge for 

Hydro Peaking Power 

$4.50 per kilowatt of Peaking Billing 

Demand. 


tkelley on DSK125TN23PROD with NOTICES
Federal Register / Vol. 86, No. 175 / Tuesday, September 14, 2021 / Notices 51145 

2.1.2. Services Associated With 

Capacity Charge for Hydro Peaking 

Power 

The capacity charge for Hydro 

Peaking Power includes such 

transmission services as are necessary to 

integrate Southwestern’s resources in 

order to reliably deliver Hydro Peaking 

Power and associated energy to the 

Customer. This capacity charge also 

includes two Ancillary Services charges: 

Scheduling, System Control, and 

Dispatch Service; and Reactive Supply 

and Voltage Control from Generation 

Sources Service. 

2.1.3. Secondary Transmission Service 

Under Capacity Associated With Hydro 

Peaking Power 

Customers may utilize the 

transmission capacity associated with 

Peaking Contract Demand for the 

transmission of non-Federal energy, on 

a non-firm, as-available basis, at no 

additional charge for such transmission 

service or associated Ancillary Services, 

under the following terms and 

conditions: 

2.1.3.1. The sum of the capacity, for 

any hour, which is used for Peaking 

Energy, Supplemental Peaking Energy, 

and Secondary Transmission Service, 

may not exceed the Peaking Contract 

Demand; 

2.1.3.2. The non-Federal energy 

transmitted under such secondary 

service is delivered to the Customer’s 

point of delivery for Hydro Peaking 

Power; 

2.1.3.3. The Customer commits to 

provide Real Power Losses associated 

with such deliveries of non-Federal 

energy; and 

2.1.3.4. Sufficient transfer capability 

exists between the point of receipt into 

the System of Southwestern of such 

non-Federal energy and the Customer’s 

point of delivery for Hydro Peaking 

Power for the time period that such 

secondary transmission service is 

requested. 

2.1.4. Adjustment for Reduction in 

Service 

If, during any month, the Peaking 

Contract Demand associated with a 

Power Sales Contract in which 

Southwestern has the obligation to 

provide 1,200 kilowatthours of Peaking 

Energy per kilowatt of Peaking Contract 

Demand is reduced by Southwestern for 

a period or periods of not less than two 

consecutive hours by reason of an 

outage caused by either an 

Uncontrollable Force or by the 

installation, maintenance, replacement 

or malfunction of generation, 

transmission and/or related facilities on 

the System of Southwestern, or 

insufficient pool levels, the Customer’s 

capacity charges for such month will be 

reduced for each such reduction in 

service by an amount computed under 

the formula: 

R = (C × K × H) ÷ S 

with the factors defined as follows: 

R = The dollar amount of reduction in the 

monthly total capacity charges for a 

particular reduction of not less than two 

consecutive hours during any month, 

except that the total amount of any such 

reduction shall not exceed the product of 

the Customer’s capacity charges 

associated with Hydro Peaking Power 

times the Peaking Billing Demand. 

C = The Customer’s capacity charges 

associated with Hydro Peaking Power for 

the Peaking Billing Demand for such 

month. 

K = The reduction in kilowatts in Peaking 

Billing Demand for a particular event. 

H = The number of hours duration of such 

particular reduction. 

S = The number of hours that Peaking Energy 

is scheduled during such month, but not 

less than 60 hours times the Peaking 

Contract Demand. 

Such reduction in charges shall fulfill 

Southwestern’s obligation to deliver 

Hydro Peaking Power and Peaking 

Energy. 

2.2. Peaking Energy and Supplemental 

Peaking Energy Rates, Terms, and 

Conditions 

2.2.1. Peaking Energy Charge 

$0.0094 per kilowatthour of Peaking 

Energy delivered plus the Purchased 

Power Adder as defined in Section 2.2.3 

of this Rate Schedule. 

2.2.2. Supplemental Energy Charge 

$0.0094 per kilowatthour of 

Supplemental Peaking Energy delivered. 

2.2.3. Purchased Power Adder 

A purchased power adder of $0.0059 

per kilowatthour of Peaking Energy 

delivered, as adjusted by the 

Administrator, Southwestern, in 

accordance with the procedure within 

this Rate Schedule. 

2.2.3.1. Applicability of Purchased 

Power Adder 

The Purchased Power Adder shall 

apply to sales of Peaking Energy. The 

Purchased Power Adder shall not apply 

to sales of Supplemental Peaking Energy 

or sales to any Customer which, by 

contract, has assumed the obligation to 

supply energy to fulfill the minimum of 

1,200 kilowatthours of Peaking Energy 

per kilowatt of Peaking Contract 

Demand during a contract year 

(hereinafter ‘‘Contract Support 

Arrangements’’). 

2.2.3.2. Procedure for Determining Net 

Purchased Power Adder Adjustment 

Not more than twice annually, the 

Purchased Power Adder of $0.0059 (5.9 

mills) per kilowatthour of Peaking 

Energy, as noted in this Rate Schedule, 

may be adjusted by the Administrator, 

Southwestern, by an amount up to a 

total of b$0.0059 (5.9 mills) per 

kilowatthour per year, as calculated by 

the following formula: 

ADJ = (PURCH ¥ EST + DIF) ÷ SALES 

with the factors defined as follows: 

ADJ = The dollar per kilowatthour amount of 

the total adjustment, plus or minus, to be 

applied to the net Purchased Power 

Adder, rounded to the nearest $0.0001 

per kilowattTMhour, provided that the 

total ADJ to be applied in any year shall 

not vary from the then-effective ADJ by 

more than $0.0059 per kilowatthour; 

PURCH = The actual total dollar cost of 

Southwestern’s System Direct Purchases 

as accounted for in the financial records 

of the Southwestern Federal Power 

System for the period; 

EST = The estimated total dollar cost 

($13,273,800 per year) of Southwestern’s 

System Direct Purchases used as the 

basis for the Purchased Power Adder of 

$0.0059 per kilowattTMhour of Peaking 

Energy; 

DIF = The accumulated remainder of the 

difference in the actual and estimated 

total dollar cost of Southwestern’s 

System Direct Purchases since the 

effective date of the currently approved 

Purchased Power Adder set forth in this 

Rate Schedule, which remainder is not 

projected for recovery through the ADJ in 

any previous periods; 

SALES = The annual Total Peaking Energy 

sales projected to be delivered 

(2,241,300,000 KWh per year) from the 

System of Southwestern, which total was 

used as the basis for the $0.0059 per 

kilowatthour Purchased Power Adder. 

2.3 Transformation Service Rates, 

Terms, and Conditions 

2.3.1 Monthly Capacity Charge for 

Transformation Service 

$0.46 per kilowatt will be assessed for 

capacity used to deliver energy at any 

point of delivery at which Southwestern 

provides transformation service for 

deliveries at voltages of 69 kilovolts or 

less from higher voltage facilities. 

2.3.2 Applicability of Capacity Charge 

for Transformation Service 

Unless otherwise specified by 

contract, for any particular month, a 

charge for transformation service will be 

assessed on the greater of (1) that 

month’s highest metered demand, or (2) 

the highest metered demand recorded 

during the previous 11 months, at any 

point of delivery. For the purpose of this 

Rate Schedule, the highest metered 

demand will be based on all deliveries, 


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51146 Federal Register / Vol. 86, No. 175 / Tuesday, September 14, 2021 / Notices 

1The average annual use of energy from storage 

for Regulation and Frequency Response Service is 

based on Southwestern studies. 

of both Federal and non-Federal energy, 

from the System of Southwestern, at 

such point during such month. 

2.4. Ancillary Services Rates, Terms, 

and Conditions 

2.4.1. Capacity Charges for Ancillary 

Services 

2.4.1.1. Regulation and Frequency 

Response Service 

Monthly rate of $0.07 per kilowatt of 

Peaking Billing Demand plus the 

Regulation Purchased Adder as defined 

in Section 2.4.5 of this Rate Schedule. 

2.4.1.2. Spinning Operating Reserve 

Service 

Monthly rate of $0.0146 per kilowatt 

of Peaking Billing Demand. 

Daily rate of $0.00066 per kilowatt for 

non-Federal generation inside 

Southwestern’s Balancing Authority 

Area. 

2.4.1.3. Supplemental Operating 

Reserve Service 

Monthly rate of $0.0146 per kilowatt 

of Peaking Billing Demand. 

Daily rate of $0.00066 per kilowatt for 

non-Federal generation inside 

Southwestern’s Balancing Authority 

Area. 

2.4.1.4. Energy Imbalance Service 

$0.0 per kilowatt for all reservation 

periods. 

2.4.2. Availability of Ancillary Services 

Regulation and Frequency Response 

Service and Energy Imbalance Service 

are available only for deliveries of 

power and energy to load within 

Southwestern’s Balancing Authority 

Area. Spinning Operating Reserve 

Service and Supplemental Operating 

Reserve Service are available only for 

deliveries of non-Federal power and 

energy generated by resources located 

within Southwestern’s Balancing 

Authority Area and for deliveries of all 

Hydro Peaking Power and associated 

energy from and within Southwestern’s 

Balancing Authority Area. Where 

available, such Ancillary Services must 

be taken from Southwestern; unless, 

arrangements are made in accordance 

with Section 2.4.4 of this Rate Schedule. 

2.4.3. Applicability of Charges for 

Ancillary Services 

For any month, the charges for 

Ancillary Services for deliveries of 

Hydro Peaking Power shall be based on 

the Peaking Billing Demand. 

The daily charge for Spinning 

Operating Reserve Service and 

Supplemental Operating Reserve 

Service for non-Federal generation 

inside Southwestern’s Balancing 

Authority Area shall be applied to the 

greater of Southwestern’s previous day’s 

estimate of the peak, or the actual peak, 

in kilowatts, of the internal non-Federal 

generation. 

2.4.4. Provision of Ancillary Services by 

Others 

Customers for which Ancillary 

Services are made available as specified 

above, must inform Southwestern by 

written notice of the Ancillary Services 

which they do not intend to take and 

purchase from Southwestern, and of 

their election to provide all or part of 

such Ancillary Services from their own 

resources or from a third party. 

Subject to Southwestern’s approval of 

the ability of such resources or third 

parties to meet Southwestern’s technical 

and operational requirements for 

provision of such Ancillary Services, 

the Customer may change the Ancillary 

Services which it takes from 

Southwestern and/or from other sources 

at the beginning of any month upon the 

greater of 60 days notice or upon 

completion of any necessary equipment 

modifications necessary to 

accommodate such change; Provided, 

That, if the Customer chooses not to 

take Regulation and Frequency 

Response Service, which includes the 

associated Regulation Purchased Adder, 

the Customer must pursue these 

services from a different host Balancing 

Authority; thereby moving all metered 

loads and resources from 

Southwestern’s Balancing Authority 

Area to the Balancing Authority Area of 

the new host Balancing Authority. Until 

such time as that meter reconfiguration 

is accomplished, the Customer will be 

charged for the Regulation and 

Frequency Response Service and 

applicable Adder then in effect. The 

Customer must notify Southwestern by 

July 1 of this choice, to be effective the 

subsequent calendar year. 

2.4.5. Regulation Purchased Adder 

Southwestern has determined the 

amount of energy used from storage to 

provide Regulation and Frequency 

Response Service in order to meet 

Southwestern’s Balancing Authority 

Area requirements. The replacement 

value of such energy used shall be 

recovered through the Regulation 

Purchased Adder. The Regulation 

Purchased Adder during the time period 

of January 1 through December 31 of the 

current calendar year is based on the 

average annual use of energy from 

storage 1 for Regulation and Frequency 

Response Service and Southwestern’s 

estimated purchased power price for the 

corresponding year from the most 

currently approved Power Repayment 

Studies. 

The Regulation Purchased Adder will 

be phased in over a period of four (4) 

years as follows: 

Year Regulation purchased adder for the incremental replacement value of energy used from storage 

2014 ............................... 1⁄4 of the average annual use of energy from storage × 2014 Purchased Power price. 

2015 ............................... 1⁄2 of the average annual use of energy from storage × 2015 Purchased Power price. 

2016 ............................... 3⁄4 of the average annual use of energy from storage × 2016 Purchased Power price. 

2017 and thereafter ....... The total average annual use of energy from storage × the applicable Purchased Power price. 

2.4.5.1. Applicability of Regulation 

Purchased Adder 

The replacement value of the 

estimated annual use of energy from 

storage for Regulation and Frequency 

Response Service shall be recovered by 

Customers located within 

Southwestern’s Balancing Authority 

Area on a non-coincident peak ratio 

share basis, divided into twelve equal 

monthly payments, in accordance with 

the formula in Section 2.4.5.2. 

If the Regulation Purchased Adder is 

determined and applied under 

Southwestern’s Rate Schedule NFTS– 

13A, then it shall not be applied here. 

2.4.5.2. Procedure for Determining 

Regulation Purchased Adder 

Unless otherwise specified by 

contract, the Regulation Purchased 

Adder for an individual Customer shall 

be based on the following formula rate, 

calculated to include the replacement 

value of the estimated annual use of 


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Federal Register / Vol. 86, No. 175 / Tuesday, September 14, 2021 / Notices 51147 

2Scheduled Exports and Scheduled Imports are 

transactions, such as sales and purchases 

respectively, which are in addition to a Customer’s metered load that contribute to Southwestern’s 

Balancing Authority Area need for regulation. 

energy from storage by Southwestern for 

Regulation and Frequency Response 

Service. 

RPA = The Regulation Purchased Adder 

for an individual Customer per 

month, which is as follows: 

[(L Customer ÷ L Total) × RP Total ] ÷ 12 

with the factors defined as follows: 

L Customer = The sum in MW of the following 

three factors: 

(1) The Customer’s highest metered load 

plus generation used to serve the 

Customer’s load that is accounted for 

through a reduction in the Customer’s 

metered load (referred to as ‘generation 

behind the meter’) during the previous 

calendar year, and 

(2) The Customer’s highest rate of 

Scheduled Exports 2 during the previous 

calendar year, and 

(3) The Customer’s highest rate of 

Scheduled Imports 2 during the previous 

calendar year. 

L Total = The sum of all L Customer factors 

for all Customers that were inside 

Southwestern’s Balancing Authority 

Area at the beginning of the previous 

calendar year in MW. 

RP Total = The ‘‘net’’ cost in dollars and cents 

based on Southwestern’s estimated 

purchased power price for the 

corresponding year from the most 

currently approved Power Repayment 

Studies multiplied by the average annual 

use of energy from storage, as provided 

for in the table in Section 2.4.5, to 

support Southwestern’s ability to 

regulate within its Balancing Authority 

Area. The ‘‘net’’ cost in dollars and cents 

shall be adjusted by subtracting the 

product of the quantity of such average 

annual use of energy from storage in 

MWh and Southwestern’s highest rate in 

dollars per MWh for Supplemental 

Peaking Energy during the previous 

calendar year. 

For Customers that have aggregated 

their load, resources, and scheduling 

into a single node by contract within 

Southwestern’s Balancing Authority 

Area, the individual Customer’s 

respective Regulation Purchased Adder 

shall be that Customer’s ratio share of 

the Regulation Purchased Adder 

established for the node. Such ratio 

share shall be determined for the 

Customer on a non-coincident basis and 

shall be calculated for the Customer 

from their highest metered load plus 

generation behind the meter. 

2.4.6. Energy Imbalance Service 

Limitations 

Energy Imbalance Service primarily 

applies to deliveries of power and 

energy which are required to satisfy a 

Customer’s load. As Hydro Peaking 

Power and associated energy are limited 

by contract, the Energy Imbalance 

Service bandwidth specified for NonFederal Transmission Service does not 

apply to deliveries of Hydro Peaking 

Power, and therefore Energy Imbalance 

Service is not charged on such 

deliveries. Customers who consume a 

capacity of Hydro Peaking Power greater 

than their Peaking Contract Demand 

may be subject to a Capacity Overrun 

Penalty. 

3. Hydro Peaking Power Penalties, 

Terms, and Conditions 

3.1. Capacity Overrun Penalty 

3.1.1. Penalty Charge for Capacity 

Overrun 

For each hour during which Hydro 

Peaking Power was provided at a rate 

greater than that to which the Customer 

is entitled, the Customer will be charged 

a Capacity Overrun Penalty at the 

following rates: 

Months associated with charge Rate per 

kilowatt 

March, April, May, October, November, December ............................................................................................................................ $0.15 

January, February, June, July, August, September ............................................................................................................................ 0.30 

3.1.2. Applicability of Capacity Overrun 

Penalty 

Customers which have loads within 

Southwestern’s Balancing Authority 

Area are obligated by contract to 

provide resources, over and above the 

Hydro Peaking Power and associated 

energy purchased from Southwestern, 

sufficient to meet their loads. A 

Capacity Overrun Penalty shall be 

applied only when the formulas 

provided in Customers’ respective 

Power Sales Contracts indicate an 

overrun on Hydro Peaking Power, and 

investigation determines that all 

resources, both firm and non-firm, 

which were available at the time of the 

apparent overrun were insufficient to 

meet the Customer’s load. 

3.2. Energy Overrun Penalty 

3.2.1. Penalty Charge for Energy 

Overrun 

$0.1034 per kilowatthour for each 

kilowatthour of overrun. 

3.2.2. Applicability of Energy Overrun 

Penalty 

By contract, the Customer is subject to 

limitations on the maximum amounts of 

Peaking Energy which may be 

scheduled under the Customer’s Power 

Sales Contract. When the Customer 

schedules an amount in excess of such 

maximum amounts, such Customer is 

subject to the Energy Overrun Penalty. 

3.3. Power Factor Penalty 

3.3.1. Requirements Related to Power 

Factor 

Any Customer served from facilities 

owned by or available by contract to 

Southwestern will be required to 

maintain a power factor of not less than 

95 percent and will be subject to the 

following provisions. 

3.3.2. Determination of Power Factor 

The power factor will be determined 

for all Demand Periods and shall be 

calculated under the formula: 

with the factors defined as follows: 

PF = The power factor for any Demand 

Period of the month. 

kWh = The total quantity of energy which is 

delivered during such Demand Period to 

the point of delivery or interconnection 

in accordance with Section 3.3.4. 

rkVAh = The total quantity of reactive 

kilovolt-ampere-hours (kVARs) delivered 

during such Demand Period to the point 

of delivery or interconnection in 

accordance with Section 3.3.4. 

3.3.3. Penalty Charge for Power Factor 

The Customer shall be assessed a 

penalty for all Demand Periods of a 

month where the power factor is less 

than 95 percent lagging. For any 

Demand Period during a particular 

month such penalty shall be in 

accordance with the following formula: 

C = D × (0.95¥LPF) × $0.10 

with the factors defined as follows: 

C = The charge in dollars to be assessed for 

any particular Demand Period of such 

month that the determination of power 


tkelley on DSK125TN23PROD with NOTICESEN14SE21.000</GPH>

PF= (kWh)+ ✓ (kWh2 + rkVAh2) 
51148 Federal Register / Vol. 86, No. 175 / Tuesday, September 14, 2021 / Notices 

factor ‘‘PF’’ is calculated to be less than 

95 percent lagging. 

D = The Customer’s demand in kilowatts at 

the point of delivery for such Demand 

Period in which a low power factor was 

calculated. 

LPF = The lagging power factor, if any, 

determined by the formula ‘‘PF’’ for such 

Demand Period. 

If C is negative, then C = zero (0). 

3.3.4. Applicability of Power Factor 

Penalty 

The Power Factor Penalty is 

applicable to radial interconnections 

with the System of Southwestern. The 

total Power Factor Penalty for any 

month shall be the sum of all charges 

‘‘C’’ for all Demand Periods of such 

month. No penalty is assessed for 

leading power factor. Southwestern, in 

its sole judgment and at its sole option, 

may determine whether power factor 

calculations should be applied to (i) a 

single physical point of delivery, (ii) a 

combination of physical points of 

delivery where a Customer has a single, 

electrically integrated load, (iii) or 

interconnections. The general criteria 

for such decision shall be that, given the 

configuration of the Customer’s and 

Southwestern’s systems, Southwestern 

will determine, in its sole judgment and 

at its sole option, whether the power 

factor calculation more accurately 

assesses the detrimental impact on 

Southwestern’s system when the above 

formula is calculated for a single 

physical point of delivery, a 

combination of physical points of 

delivery, or for an interconnection as 

specified by an Interconnection 

Agreement. 

Southwestern, at its sole option, may 

reduce or waive Power Factor Penalties 

when, in Southwestern’s sole judgment, 

low power factor conditions were not 

detrimental to the System of 

Southwestern due to particular loading 

and voltage conditions at the time the 

power factor dropped below 95 percent 

lagging. 

4. Hydro Peaking Power Miscellaneous 

Rates, Terms, and Conditions 

4.1. Real Power Losses 

Customers are required to self-provide 

all Real Power Losses for non-Federal 

energy transmitted by Southwestern on 

behalf of such Customers under the 

provisions detailed below. 

Real Power Losses are computed as 

four (4) percent of the total amount of 

non-Federal energy transmitted by 

Southwestern. The Customer’s monthly 

Real Power Losses are computed each 

month on a megawatthour basis as 

follows: 

ML = 0.04 × NFE 

with the factors defined as follows: 

ML = The total monthly loss energy, rounded 

to the nearest megawatthour, to be 

scheduled by a Customer for receipt by 

Southwestern for Real Power Losses 

associated with non-Federal energy 

transmitted on behalf of such Customer; 

and 

NFE = The amount of non-Federal energy 

that was transmitted by Southwestern on 

behalf of a Customer during a particular 

month. 

The Customer must schedule or cause 

to be scheduled to Southwestern, Real 

Power Losses for which it is responsible 

subject to the following conditions: 

4.1.1. The Customer shall schedule 

and deliver Real Power Losses back to 

Southwestern during the second month 

after they were incurred by 

Southwestern in the transmission of the 

Customer’s non-Federal power and 

energy over the System of Southwestern 

unless such Customer has accounted for 

Real Power Losses as part of a metering 

arrangement with Southwestern. 

4.1.2. On or before the twentieth day 

of each month, Southwestern shall 

determine the amount of non-Federal 

loss energy it provided on behalf of the 

Customer during the previous month 

and provide a written schedule to the 

Customer setting forth hour-by-hour the 

quantities of non-Federal energy to be 

delivered to Southwestern as losses 

during the next month. 

4.1.3. Real Power Losses not delivered 

to Southwestern by the Customer, 

according to the schedule provided, 

during the month in which such losses 

are due shall be billed by Southwestern 

to the Customer to adjust the end-ofmonth loss energy balance to zero (0) 

megawatthours and the Customer shall 

be obliged to purchase such energy at 

the following rates: 

Months associated with charge Rate per 

kilowatthour 

March, April, May, October, November, December ............................................................................................................................ $0.15 

January, February, June, July, August, September ............................................................................................................................ 0.30 

4.1.4. Real Power Losses delivered to 

Southwestern by the Customer in excess 

of the losses due during the month shall 

be purchased by Southwestern from the 

Customer at a rate per megawatthour 

equal to Southwestern’s rate per 

megawatthour for Supplemental 

Peaking Energy, as set forth in 

Southwestern’s then-effective Rate 

Schedule for Hydro Peaking Power to 

adjust such hourly end-of-month loss 

energy balance to zero (0) 

megawatthours. 

4.2. Peaking Energy Schedule 

Submission Time 

Southwestern’s Peaking Energy 

Schedule Submission Time is on or 

before 2:30 p.m. Central Prevailing Time 

(CPT), as adjusted by the Administrator, 

Southwestern, in accordance with 

Section 4.2.2 in this Rate Schedule, of 

the day preceding the day for the 

delivery of Peaking Energy. The Peaking 

Energy Schedule Submission Time 

supersedes the Peaking Energy schedule 

submission time provided in the 

Customer’s Power Sales Contract, 

pursuant to Section 4.2.1 of this Rate 

Schedule. 

4.2.1. Applicability of Peaking Energy 

Schedule Submission Time 

The Peaking Energy Schedule 

Submission Time shall apply to the 

scheduling of Peaking Energy. The 

Peaking Energy Schedule Submission 

Time shall not apply to the scheduling 

of Supplemental Peaking Energy or to 

Contract Support Arrangements. 

4.2.2. Procedure for Adjusting the 

Peaking Energy Schedule Submission 

Time 

Not more than once annually, the 

Peaking Energy Schedule Submission 

Time of 2:30 p.m. CPT, as noted in 

Section 4.2 of this Rate Schedule, may 

be adjusted by the Administrator, 

Southwestern, to a time no earlier than 

2:00 p.m. CPT and no later than 3:00 

p.m. CPT. 

4.2.2.1. Determination of Need To 

Adjust the Peaking Energy Schedule 

Submission Time 

The Administrator, Southwestern, 

will make a determination on the need 

to adjust the Peaking Energy Schedule 

Submission Time based on 

Southwestern’s studies involving 

financial analysis, regional energy 


tkelley on DSK125TN23PROD with NOTICES
Federal Register / Vol. 86, No. 175 / Tuesday, September 14, 2021 / Notices 51149 

1Supersedes Rate Schedule NFTS–13. 

** Extended through September 30, 2023, by 

approval of Rate Order No. SWPA–77 by the 

Administrator, Southwestern Power 

Administration. 

market conditions, and/or operational 

considerations. 

4.2.2.2. Notification of Peaking Energy 

Schedule Submission Time Adjustment 

The Administrator, Southwestern, 

will notify customers of the 

determination to adjust the Peaking 

Energy Schedule Submission Time in 

writing no later than 30 calendar days 

prior to the effective date of the Peaking 

Energy Schedule Submission Time 

adjustment. 

UNITED STATES DEPARTMENT OF 

ENERGY 

SOUTHWESTERN POWER 

ADMINISTRATION 

RATE SCHEDULE NFTS–13A 1 ** 

WHOLESALE RATES FOR NONFEDERAL TRANSMISSION/ 

INTERCONNECTION FACILITIES 

SERVICE 

Effective: During the period October 1, 

2013, through September 30, 2023,** in 

accordance with the Federal Energy 

Regulatory Commission (FERC) order 

issued in Docket No. EF14–1–000 (Jan. 

9, 2014), modification approved by 

FERC in Docket No. EF14–1–001 (Mar. 

9, 2017), extension approved by the 

Deputy Secretary in Docket No. EF14– 

1–002 (Sept. 13, 2017), extension 

approved by Assistant Secretary for 

Electricity in Rate Order No. 74 (Sept. 

22, 2019), and extension approved by 

the Administrator in Rate Order No. 77 

(August 30, 2021). 

Available: In the region of the System 

of Southwestern. 

Applicable: To Customers which have 

executed Service Agreements with 

Southwestern for the transmission of 

non-Federal power and energy over the 

System of Southwestern or for its use for 

interconnections. Southwestern will 

provide services over those portions of 

the System of Southwestern in which 

the Administrator, Southwestern, in his 

or her sole judgment, has determined 

that uncommitted transmission and 

transformation capacities in the System 

of Southwestern are and will be 

available in excess of the capacities 

required to market Federal power and 

energy pursuant to Section 5 of the 

Flood Control Act of 1944 (58 Stat. 

887,890; 16 U.S.C. 825s). 

Character and Conditions of Service: 

Three-phase, alternating current, 

delivered at approximately 60 Hertz, at 

the nominal voltage(s), at the point(s) 

specified by Service Agreement or 

Transmission Service Transaction. 

1. Definitions of Terms 

1.1. Ancillary Services 

The services necessary to support the 

transmission of capacity and energy 

from resources to loads while 

maintaining reliable operation of the 

System of Southwestern in accordance 

with good utility practice, which 

include the following: 

1.1.1. Scheduling, System Control, and 

Dispatch Service 

is provided by Southwestern as 

Balancing Authority Area operator and 

is in regard to interchange and loadmatch scheduling and related system 

control and dispatch functions. 

1.1.2. Reactive Supply and Voltage 

Control From Generation Sources 

Service 

is provided at transmission facilities in 

the System of Southwestern to produce 

or absorb reactive power and to 

maintain transmission voltages within 

specific limits. 

1.1.3. Regulation and Frequency 

Response Service 

is the continuous balancing of 

generation and interchange resources 

accomplished by raising or lowering the 

output of on-line generation as 

necessary to follow the moment-bymoment changes in load and to 

maintain frequency within a Balancing 

Authority Area. 

1.1.4. Spinning Operating Reserve 

Service 

maintains generating units on-line, but 

loaded at less than maximum output, 

which may be used to service load 

immediately when disturbance 

conditions are experienced due to a 

sudden loss of generation or load. 

1.1.5. Supplemental Operating Reserve 

Service 

provides an additional amount of 

operating reserve sufficient to reduce 

Area Control Error to zero within 10 

minutes following loss of generating 

capacity which would result from the 

most severe single contingency. 

1.1.6. Energy Imbalance Service 

corrects for differences over a period of 

time between schedules and actual 

hourly deliveries of energy to a load. 

Energy delivered or received within the 

authorized bandwidth for this service is 

accounted for as an inadvertent flow 

and is returned to the providing party 

by the receiving party in accordance 

with standard utility practice or a 

contractual arrangement between the 

parties. 

1.2. Customer 

The entity which is utilizing and/or 

purchasing Federal Power and Federal 

Energy and services from Southwestern 

pursuant to this Rate Schedule. 

1.3. Demand Period 

The period of time used to determine 

maximum integrated rates of delivery 

for the purpose of power accounting 

which is the 60-minute period that 

begins with the change of hour. 

1.4. Firm Point-to-Point Transmission 

Service 

Transmission service reserved on a 

firm basis between specific points of 

receipt and delivery pursuant to either 

a Firm Transmission Service Agreement 

or to a Transmission Service 

Transaction. 

1.5. Interconnection Facilities Service 

A service that provides for the use of 

the System of Southwestern to deliver 

energy and/or provide system support at 

an interconnection. 

1.6. Network Integration Transmission 

Service 

Transmission service provided under 

Part III of Southwestern’s Open Access 

Transmission Service Tariff which 

provides the Customer with firm 

transmission service for the delivery of 

capacity and energy from the 

Customer’s resources to the Customer’s 

load. 

1.7. Non-Firm Point-to-Point 

Transmission Service 

Transmission service reserved on a 

non-firm basis between specific points 

of receipt and delivery pursuant to a 

Transmission Service Transaction. 

1.8. Point of Delivery 

Either a single physical point to 

which electric power and energy are 

delivered from the System of 

Southwestern, or a specified set of 

delivery points which together form a 

single, electrically integrated load. 

1.9. Secondary Transmission Service 

Service that is associated with Firm 

Point-to-Point Transmission Service and 

Network Integration Transmission 

Service. For Firm Point-to-Point 

Transmission Service, it consists of 

transmission service provided on an asavailable, non-firm basis, scheduled 

within the limits of a particular capacity 

reservation for transmission service, and 

scheduled from points of receipt, or to 

points of delivery, other than those 


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51150 Federal Register / Vol. 86, No. 175 / Tuesday, September 14, 2021 / Notices 

designated in a Long-Term Firm 

Transmission Service Agreement or a 

Transmission Service Transaction for 

Firm Point-to-Point Transmission 

Service. For Network Integration 

Transmission Service, Secondary 

Transmission Service consists of 

transmission service provided on an asavailable, non-firm basis, from resources 

other than the network resources 

designated in a Network Transmission 

Service Agreement, to meet the 

Customer’s network load. The charges 

for Secondary Transmission Service, 

other than Ancillary Services, are 

included in the applicable capacity 

charges for Firm Point-to-Point 

Transmission Service and Network 

Integration Transmission Service. 

1.10. Service Agreement 

A contract executed between a 

Customer and Southwestern for the 

transmission of non-Federal power and 

energy over the System of Southwestern 

or for interconnections which include 

the following: 

1.10.1. Firm Transmission Service 

Agreement 

provides for reserved transmission 

capacity on a firm basis, for a particular 

point-to-point delivery path. 

1.10.2. Interconnection Agreement 

provides for the use of the System of 

Southwestern and recognizes the 

exchange of mutual benefits for such 

use or provides for application of a 

charge for Interconnection Facilities 

Service. 

1.10.3. Network Transmission Service 

Agreement 

provides for the Customer to request 

firm transmission service for the 

delivery of capacity and energy from the 

Customer’s network resources to the 

Customer’s network load, for a period of 

one year or more. 

1.10.4. Non-Firm Transmission Service 

Agreement 

provides for the Customer to request 

transmission service on a non-firm 

basis. 

1.11. Service Request 

The request made under a 

Transmission Service Agreement 

through the Southwest Power Pool, Inc. 

(hereinafter ‘‘SPP’’) Open Access SameTime Information System (hereinafter 

‘‘OASIS’’) for reservation of 

transmission capacity over a particular 

point-to-point delivery path for a 

particular period. The Customer must 

submit hourly schedules for actual 

service in addition to the Service 

Request. 

1.12. System of Southwestern 

The transmission and related facilities 

owned by Southwestern, and/or the 

generation, transmission, and related 

facilities owned by others, the capacity 

of which, by contract, is available to and 

utilized by Southwestern to satisfy its 

contractual obligations to the Customer. 

1.13. Transmission Service Transaction 

A Service Request that has been 

approved by SPP. 

1.14. Uncontrollable Force 

Any force which is not within the 

control of the party affected, including, 

but not limited to failure of water 

supply, failure of facilities, flood, 

earthquake, storm, lightning, fire, 

epidemic, riot, civil disturbance, labor 

disturbance, sabotage, war, act of war, 

terrorist acts, or restraint by court of 

general jurisdiction, which by exercise 

of due diligence and foresight such 

party could not reasonably have been 

expected to avoid. 

2. Wholesale Rates, Terms, and 

Conditions for Firm Point-to-Point 

Transmission Service, Non-Firm Pointto-Point Transmission Service, Network 

Integration Transmission Service, and 

Interconnection Facilities Service 

2.1. Firm Point-to-Point Transmission 

Service Rates, Terms, and Conditions 

2.1.1. Monthly Capacity Charge for Firm 

Point-to-Point Transmission Service 

$1.48 per kilowatt of transmission 

capacity reserved in increments of one 

month of service or invoiced in 

accordance with a longer term 

agreement. 

2.1.2. Weekly Capacity Charge for Firm 

Point-to-Point Transmission Service 

$0.370 per kilowatt of transmission 

capacity reserved in increments of one 

week of service. 

2.1.3. Daily Capacity Charge for Firm 

Point-to-Point Transmission Service 

$0.0673 per kilowatt of transmission 

capacity reserved in increments of one 

day of service. 

2.1.4. Services Associated With 

Capacity Charge for Firm Point-to-Point 

Transmission Service 

The capacity charge for Firm Point-toPoint Transmission Service includes 

Secondary Transmission Service, but 

does not include charges for Ancillary 

Services associated with actual 

schedules. 

2.1.5. Applicability of Capacity Charge 

for Firm Point-to-Point Transmission 

Service 

Capacity charges for Firm Point-toPoint Transmission Service are applied 

to quantities reserved by contract under 

a Firm Transmission Service Agreement 

or in accordance with a Transmission 

Service Transaction. 

A Customer, unless otherwise 

specified by contract, will be assessed 

capacity charges on the greatest of (1) 

the highest metered demand at any 

particular Point of Delivery during a 

particular month, rounded up to the 

nearest whole megawatt, or (2) the 

highest metered demand recorded at 

such Point of Delivery during any of the 

previous 11 months, rounded up to the 

nearest whole megawatt, or (3) the 

capacity reserved by contract; which 

amount shall be considered such 

Customer’s reserved capacity. 

Secondary Transmission Service for 

such Customer shall be limited during 

any month to the most recent metered 

demand on which that Customer is 

billed or to the capacity reserved by 

contract, whichever is greater. 

2.2. Non-Firm Point-to-Point 

Transmission Service Rates, Terms, and 

Conditions 

2.2.1. Monthly Capacity Charge for NonFirm Point-to-Point Transmission 

Service 

80 percent of the monthly capacity 

charge for Firm Point-to-Point 

Transmission Service reserved in 

increments of one month. 

2.2.2. Weekly Capacity Charge for NonFirm Point-to-Point Transmission 

Service 

80 percent of the monthly capacity 

charge divided by 4 for Firm Point-toPoint Transmission Service reserved in 

increments of one week. 

2.2.3. Daily Capacity Charge for NonFirm Point-to-Point Transmission 

Service 

80 percent of the monthly capacity 

charge divided by 22 for Firm Point-toPoint Transmission Service reserved in 

increments of one day. 

2.2.4. Hourly Capacity Charge for NonFirm Point-to-Point Transmission 

Service 

80 percent of the monthly capacity 

charge divided by 352 for Firm Point-toPoint Transmission Service reserved in 

increments of one hour. 


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2.2.5. Applicability of Charges for NonFirm Point-to-Point Transmission 

Service 

Capacity charges for Non-Firm Pointto-Point Transmission Service are 

applied to quantities reserved under a 

Transmission Service Transaction, and 

do not include charges for Ancillary 

Services. 

2.3. Network Integration Transmission 

Service Rates, Terms, and Conditions 

2.3.1. Annual Revenue Requirement for 

Network Integration Transmission 

Service 

$15,533,800. 

2.3.2. Monthly Revenue Requirement for 

Network Integration Transmission 

Service 

$1,294,483. 

2.3.3. Net Capacity Available for 

Network Integration Transmission 

Service 

872,000 kilowatts. 

2.3.4. Monthly Capacity Charge for 

Network Integration Transmission 

Service 

$1.48 per kilowatt of Network Load 

(charge derived from $1,294,483 ÷ 

872,000 kilowatts). 

2.3.5. Applicability of Charges for 

Network Integration Transmission 

Service 

Network Integration Transmission 

Service is available only for deliveries of 

non-Federal power and energy, and is 

applied to the Customer utilizing such 

service exclusive of any deliveries of 

Federal power and energy. The capacity 

on which charges for any particular 

Customer utilizing this service is 

determined on the greatest of (1) the 

highest metered demand at any 

particular point of delivery during a 

particular month, rounded up to the 

nearest whole megawatt, or (2) the 

highest metered demand recorded at 

such point of delivery during any of the 

previous 11 months, rounded up to the 

nearest whole megawatt. 

For a Customer taking Network 

Integration Transmission Service who is 

also taking delivery of Federal Power 

and Energy, the highest metered 

demand shall be determined by 

subtracting the energy scheduled for 

delivery of Federal Power and Energy 

for any hour from the metered demand 

for such hour. 

Secondary transmission Service for a 

Customer shall be limited during any 

month to the most recent highest 

metered demand on which such 

Customer is billed. Charges for 

Ancillary Services shall also be 

assessed. 

2.3.6. Procedure for Determining SPP 

Open Access Transmission Tariff 

Network Integration Transmission 

Service Annual Revenue Requirement 

The SPP Open Access Transmission 

Tariff Network Integration Transmission 

Service Annual Revenue Requirement 

shall be based on the following formula 

which shall be calculated when a 

Customer transitions from a Service 

Agreement to an agreement for Network 

Integration Transmission Service under 

the SPP Open Access Transmission 

Tariff. 

SPP NITS ARR = Southwestern’s SPP 

Network Integration Transmission 

Service Annual Revenue 

Requirement, which is as follows: 

(SPP NITS Capacity/Southwestern NITS 

Capacity) × Southwestern NITS 

ARR 

with the factors defined as follows: 

SPP NITS Capacity = The capacity on the 

System of Southwestern utilized for SPP 

Network Integration Transmission 

Service which shall be based on the 

currently approved Power Repayment 

Studies. 

Southwestern NITS Capacity = Net Capacity 

Available for Network Integration 

Transmission Service on the System of 

Southwestern as specified in Section 

2.3.3. 

Southwestern NITS ARR = Southwestern’s 

Annual Revenue Requirement for 

Network Integration Transmission 

Service as specified in Section 2.3.1. 

2.4. Interconnection Facilities Service 

Rates, Terms, and Conditions 

2.4.1. Monthly Capacity Charge for 

Interconnection Facilities Service 

$1.48 per kilowatt. 

2.4.2. Applicability of Capacity Charge 

for Interconnection Facilities Service 

Any Customer that requests an 

interconnection from Southwestern 

which, in Southwestern’s sole judgment 

and at its sole option, does not provide 

commensurate benefits or compensation 

to Southwestern for the use of its 

facilities shall be assessed a capacity 

charge for Interconnection Facilities 

Service. For any month, charges for 

Interconnection Facilities Service shall 

be assessed on the greater of (1) that 

month’s actual highest metered demand, 

or (2) the highest metered demand 

recorded during the previous eleven 

months, as metered at the 

interconnection. The use of 

Interconnection Facilities Service will 

be subject to power factor provisions as 

specified in this Rate Schedule. The 

interconnection customer shall also 

schedule and deliver Real Power Losses 

pursuant to the provisions of this Rate 

Schedule based on metered flow 

through the interconnection where 

Interconnection Facilities Services is 

assessed. 

2.5. Transformation Service Rates, 

Terms, and Conditions 

2.5.1. Monthly Capacity Charge for 

Transformation Service 

$0.46 per kilowatt will be assessed for 

capacity used to deliver energy at any 

point of delivery at which Southwestern 

provides transformation service for 

deliveries at voltages of 69 kilovolts or 

less from higher voltage facilities. 

2.5.2. Applicability of Capacity Charge 

for Transformation Service 

Unless otherwise specified by 

contract, for any particular month, a 

charge for transformation service will be 

assessed on the greater of (1) that 

month’s highest metered demand, or (2) 

the highest metered demand recorded 

during the previous 11 months, at any 

point of delivery. For the purpose of this 

Rate Schedule, the highest metered 

demand will be based on all deliveries, 

of both Federal and non-Federal energy, 

from the System of Southwestern, at 

such point during such month. 

2.6. Ancillary Services Rates, Terms, 

and Conditions 

2.6.1. Capacity Charges for Ancillary 

Services 

2.6.1.1. Scheduling, System Control, 

and Dispatch Service 

Monthly rate of $0.09 per kilowatt of 

transmission capacity reserved in 

increments of one month of service or 

invoiced in accordance with a LongTerm Firm Transmission Service 

Agreement or Network Transmission 

Service Agreement. 

Weekly rate of $0.023 per kilowatt of 

transmission capacity reserved in 

increments of one week of service. 

Daily rate of $0.0041 per kilowatt of 

transmission capacity reserved in 

increments of one day of service. 

Hourly rate of $0.00026 per kilowatt 

of transmission energy delivered as nonfirm transmission service. 

2.6.1.2. Reactive Supply and Voltage 

Control From Generation Sources 

Service 

Monthly rate of $0.04 per kilowatt of 

transmission capacity reserved in 

increments of one month of service or 

invoiced in accordance with a LongTerm Firm Transmission Service 

Agreement or Network Transmission 

Service Agreement. 


tkelley on DSK125TN23PROD with NOTICES
51152 Federal Register / Vol. 86, No. 175 / Tuesday, September 14, 2021 / Notices 

1The average annual use of energy from storage 

for Regulation and Frequency Response Service is 

based on Southwestern studies. 

Weekly rate of $0.010 per kilowatt of 

transmission capacity reserved in 

increments of one week of service. 

Daily rate of $0.0018 per kilowatt of 

transmission capacity reserved in 

increments of one day of service. 

Hourly rate of $0.00011 per kilowatt 

of transmission energy delivered as nonfirm transmission service. 

2.6.1.3. Regulation and Frequency 

Response Service 

Monthly rate of $0.07 per kilowatt of 

transmission capacity reserved in 

increments of one month of service or 

invoiced in accordance with a LongTerm Firm Transmission Service 

Agreement or Network Transmission 

Service Agreement plus the Regulation 

Purchased Adder as defined in Section 

2.6.5 of this Rate Schedule. 

Weekly rate of $0.018 per kilowatt of 

transmission capacity reserved in 

increments of one week of service plus 

the Regulation Purchased Adder as 

defined in Section 2.6.5 of this Rate 

Schedule. 

Daily rate of $0.0032 per kilowatt of 

transmission capacity reserved in 

increments of one day of service plus 

the Regulation Purchased Adder as 

defined in Section 2.6.5 of this Rate 

Schedule. 

Hourly rate of $0.00020 per kilowatt 

of transmission energy delivered as nonfirm transmission service plus the 

Regulation Purchased Adder as defined 

in Section 2.6.5 of this Rate Schedule. 

2.6.1.4. Spinning Operating Reserve 

Service 

Monthly rate of $0.0146 per kilowatt 

of transmission capacity reserved in 

increments of one month of service or 

invoiced in accordance with a LongTerm Firm Transmission Service 

Agreement or Network Transmission 

Service Agreement. 

Weekly rate of $0.00365 per kilowatt 

of transmission capacity reserved in 

increments of one week of service. 

Daily rate of $0.00066 per kilowatt of 

transmission capacity reserved in 

increments of one day of service. 

Hourly rate of $0.00004 per kilowatt 

of transmission energy delivered as nonfirm transmission service. 

2.6.1.5. Supplemental Operating 

Reserve Service 

Monthly rate of $0.0146 per kilowatt 

of transmission capacity reserved in 

increments of one month of service or 

invoiced in accordance with a LongTerm Firm Transmission Service 

Agreement or Network Transmission 

Service Agreement. 

Weekly rate of $0.00365 per kilowatt 

of transmission capacity reserved in 

increments of one week of service. 

Daily rate of $0.00066 per kilowatt of 

transmission capacity reserved in 

increments of one day of service. 

Hourly rate of $0.00004 per kilowatt 

of transmission energy delivered as nonfirm transmission service. 

2.6.1.6. Energy Imbalance Service 

$0.0 per kilowatt for all reservation 

periods. 

2.6.2. Availability of Ancillary Services 

Scheduling, System Control, and 

Dispatch Service and Reactive Supply 

and Voltage Control from Generation 

Sources Service are available for all 

transmission services in and from the 

System of Southwestern and shall be 

provided by Southwestern. Regulation 

and Frequency Response Service and 

Energy Imbalance Service are available 

only for deliveries of power and energy 

to load within Southwestern’s Balancing 

Authority Area, and shall be provided 

by Southwestern, unless, subject to 

Southwestern’s approval, they are 

provided by others. Spinning Operating 

Reserve Service and Supplemental 

Operating Reserve Service are available 

only for deliveries of power and energy 

generated by resources located within 

Southwestern’s Balancing Authority 

Area and shall be provided by 

Southwestern, unless, subject to 

Southwestern’s approval, they are 

provided by others. 

2.6.3. Applicability of Charges for 

Ancillary Services 

Charges for all Ancillary Services are 

applied to the transmission capacity 

reserved or network transmission 

service taken by the Customer in 

accordance with the rates listed above 

when such services are provided by 

Southwestern. 

The charges for Ancillary Services are 

considered to include Ancillary 

Services for any Secondary 

Transmission Service, except in cases 

where Ancillary Services identified in 

Sections 2.6.1.3 through 2.6.1.6 of this 

Rate Schedule are applicable to a 

Transmission Service Transaction of 

Secondary Transmission Service, but 

are not applicable to the transmission 

capacity reserved under which 

Secondary Transmission Service is 

provided. When charges for Ancillary 

Services are applicable to Secondary 

Transmission Service, the charge for the 

Ancillary Service shall be the hourly 

rate applied to all energy transmitted 

utilizing the Secondary Transmission 

Service. 

2.6.4. Provision of Ancillary Services by 

Others 

Customers for which Ancillary 

Services identified in Sections 2.6.1.3 

through 2.6.1.6 of this Rate Schedule are 

made available as specified above must 

inform Southwestern by written notice 

of the Ancillary Services which they do 

not intend to take and purchase from 

Southwestern, and of their election to 

provide all or part of such Ancillary 

Services from their own resources or 

from a third party. Such notice 

requirements also apply to requests for 

Southwestern to provide Ancillary 

Services when such services are 

available as specified above. 

Subject to Southwestern’s approval of 

the ability of such resources or third 

parties to meet Southwestern’s technical 

and operational requirements for 

provision of such Ancillary Services, 

the Customer may change the Ancillary 

Services which it takes from 

Southwestern and/or from other sources 

at the beginning of any month upon the 

greater of 60 days written notice or upon 

the completion of any necessary 

equipment modifications necessary to 

accommodate such change; Provided, 

That, if the Customer chooses not to 

take Regulation and Frequency 

Response Service, which includes the 

associated Regulation Purchased Adder, 

the Customer must pursue these 

services from a different host Balancing 

Authority; thereby moving all metered 

loads and resources from 

Southwestern’s Balancing Authority 

Area to the Balancing Authority Area of 

the new host Balancing Authority. Until 

such time as that meter reconfiguration 

is accomplished, the Customer will be 

charged for the Regulation and 

Frequency Response Service and 

applicable Adder then in effect. The 

Customer must notify Southwestern by 

July 1 of this choice, to be effective the 

subsequent calendar year. 

2.6.5. Regulation Purchased Adder 

Southwestern has determined the 

amount of energy used from storage to 

provide Regulation and Frequency 

Response Service in order to meet 

Southwestern’s Balancing Authority 

Area requirements. The replacement 

value of such energy used shall be 

recovered through the Regulation 

Purchased Adder. The Regulation 

Purchased Adder during the time period 

of January 1 through December 31 of the 

current calendar year is based on the 

average annual use of energy from 

storage 1 for Regulation and Frequency 


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Federal Register / Vol. 86, No. 175 / Tuesday, September 14, 2021 / Notices 51153 

2Scheduled Exports and Scheduled Imports are 

transactions, such as sales and purchases 

respectively, which are in addition to a Customer’s metered load that contribute to Southwestern’s 

Balancing Authority Area need for regulation. 

Response Service and Southwestern’s 

estimated purchased power price for the 

corresponding year from the most 

currently approved Power Repayment 

Studies. 

The Regulation Purchased Adder will 

be phased in over a period of four (4) 

years as follows: 

Year Regulation Purchased Adder for the incremental replacement value of energy used from storage 

2014 ............................... 1⁄4 of the average annual use of energy from storage × 2014 Purchased Power price. 

2015 ............................... 1⁄2 of the average annual use of energy from storage × 2015 Purchased Power price. 

2016 ............................... 3⁄4 of the average annual use of energy from storage × 2016 Purchased Power price. 

2017 and thereafter ....... The total average annual use of energy from storage × the applicable Purchased Power price. 

2.6.5.1. Applicability of Regulation 

Purchased Adder 

The replacement value of the 

estimated annual use of energy from 

storage for Regulation and Frequency 

Response Service shall be recovered by 

Customers located within 

Southwestern’s Balancing Authority 

Area on a non-coincident peak ratio 

share basis, divided into twelve equal 

monthly payments, in accordance with 

the formula in Section 2.6.5.2. 

If the Regulation Purchased Adder is 

determined and applied under 

Southwestern’s Rate Schedule P–13, 

then it shall not be applied here. 

2.6.5.2. Procedure for Determining 

Regulation Purchased Adder 

Unless otherwise specified by 

contract, the Regulation Purchased 

Adder for an individual Customer shall 

be based on the following formula rate, 

calculated to include the replacement 

value of the estimated annual use of 

energy from storage by Southwestern for 

Regulation and Frequency Response 

Service. 

RPA = The Regulation Purchased Adder 

for an individual Customer per 

month, which is as follows: 

[(L Customer ÷ L Total) × RP Total ] ÷ 12 

with the factors defined as follows: 

L Customer = The sum in MW of the following 

three factors: 

(1) The Customer’s highest metered load 

plus generation used to serve the 

Customer’s load that is accounted for 

through a reduction in the Customer’s 

metered load (referred to as ‘generation 

behind the meter’) during the previous 

calendar year, and 

(2) The Customer’s highest rate of 

Scheduled Exports 2 during the previous 

calendar year, and 

(3) The Customer’s highest rate of 

Scheduled Imports 2 during the previous 

calendar year. 

LTotal = The sum of all L Customer factors for 

all Customers that were inside 

Southwestern’s Balancing Authority 

Area at the beginning of the previous 

calendar year in MW. 

RP Total = The ‘‘net’’ cost in dollars and cents 

based on Southwestern’s estimated 

purchased power price for the 

corresponding year from the most 

currently approved Power Repayment 

Studies multiplied by the average annual 

use of energy from storage, as provided 

for in the table in Section 2.6.5, to 

support Southwestern’s ability to 

regulate within its Balancing Authority 

Area. The ‘‘net’’ cost in dollars and cents 

shall be adjusted by subtracting the 

product of the quantity of such average 

annual use of energy from storage in 

MWh and Southwestern’s highest rate in 

dollars per MWh for Supplemental 

Peaking Energy during the previous 

calendar year. 

For Customers that have aggregated 

their load, resources, and scheduling 

into a single node by contract within 

Southwestern’s Balancing Authority 

Area, the individual Customer’s 

respective Regulation Purchased Adder 

shall be that Customer’s ratio share of 

the Regulation Purchased Adder 

established for the node. Such ratio 

share shall be determined for the 

Customer on a non-coincident basis and 

shall be calculated for the Customer 

from their highest metered load plus 

generation behind the meter. 

2.6.6. Energy Imbalance Service 

Limitations 

Energy Imbalance Service is 

authorized for use only within a 

bandwidth of b1.5 percent of the actual 

requirements of the load at a particular 

point of delivery, for any hour, 

compared to the resources scheduled to 

meet such load during such hour. 

Deviations which are greater than b1.5 

percent, but which are less than b2,000 

kilowatts, are considered to be within 

the authorized bandwidth. Deviations 

outside the authorized bandwidth are 

subject to a Capacity Overrun Penalty. 

Energy delivered or received within 

the authorized bandwidth for this 

service is accounted for as an 

inadvertent flow and will be netted 

against flows in the future. The 

inadvertent flow in any given hour will 

only be offset with the flows in the 

corresponding hour of a day in the same 

category. Unless otherwise specified by 

contract, the two categories of days are 

weekdays and weekend days/North 

American Electric Reliability 

Corporation holidays, and this process 

will result in a separate inadvertent 

accumulation for each hour of the two 

categories of days. The hourly 

accumulations in the current month will 

be added to the hourly inadvertent 

balances from the previous month, 

resulting in a month-end balance for 

each hour. 

The Customer is required to adjust the 

scheduling of resources in such a way 

as to reduce the accumulation towards 

zero. It is recognized that the 

inadvertent hourly flows can be both 

negative and positive, and that offsetting 

flows should deter a significant 

accumulation of inadvertent. Unless 

otherwise specified by contract, in the 

event any hourly month-end balance 

exceeds 12 MWhs, the excess will be 

subject to Section 3.1 or Section 3.2 of 

this Rate Schedule, depending on the 

direction of the accumulation. 

3. Non-Federal Transmission/ 

Interconnection Facilities Service 

Penalties, Terms, and Conditions 

3.1. Capacity Overrun Penalty 

3.1.1. Penalty Charge for Capacity 

Overrun 

For each hour during which energy 

flows outside the authorized bandwidth, 

the Customer will be obliged to 

purchase such energy at the following 

rates: 

Months associated with charge Rate per 

kilowatt 

March, April, May, October, November, December ............................................................................................................................ $0.15 


tkelley on DSK125TN23PROD with NOTICES
51154 Federal Register / Vol. 86, No. 175 / Tuesday, September 14, 2021 / Notices 

Months associated with charge Rate per 

kilowatt 

January, February, June, July, August, September ............................................................................................................................ 0.30 

3.1.2. Applicability of Capacity Overrun 

Penalty 

Customers who receive deliveries 

within Southwestern’s Balancing 

Authority Area are obligated to provide 

resources sufficient to meet their loads. 

Such obligation is not related to the 

amount of transmission capacity that 

such Customers may have reserved for 

transmission service to a particular load. 

In the event that a Customer 

underschedules its resources to serve its 

load, resulting in a difference between 

resources and actual metered load 

(adjusted for transformer losses as 

applicable) outside the authorized 

bandwidth for Energy Imbalance Service 

for any hour, then such Customer is 

subject to the Capacity Overrun Penalty. 

3.2. Unauthorized Use of Energy 

Imbalance Service by Overscheduling of 

Resources 

In the event that a Customer 

schedules greater resources than are 

needed to serve its load, such that 

energy flows at rates beyond the 

authorized bandwidth for the use of 

Energy Imbalance Service, 

Southwestern retains such energy at no 

cost to Southwestern and with no 

obligation to return such energy. 

3.3. Power Factor Penalty 

3.3.1. Requirements Related to Power 

Factor 

Any Customer served from facilities 

owned by or available by contract to 

Southwestern will be required to 

maintain a power factor of not less than 

95 percent and will be subject to the 

following provisions. 

3.3.2. Determination of Power Factor 

The power factor will be determined 

for all Demand Periods and shall be 

calculated under the formula: 

with the factors defined as follows: 

PF = The power factor for any Demand 

Period of the month. 

kWh = The total quantity of energy which is 

delivered during such Demand Period to 

the point of delivery or interconnection 

in accordance with Section 3.3.4. 

rkVAh = The total quantity of reactive 

kilovolt-ampere-hours (kVARs) delivered 

during such Demand Period to the point 

of delivery or interconnection in 

accordance with Section 3.3.4. 

3.3.3. Penalty Charge for Power Factor 

The Customer shall be assessed a 

penalty for all Demand Periods of a 

month where the power factor is less 

than 95 percent lagging. For any 

Demand Period during a particular 

month such penalty shall be in 

accordance with the following formula: 

C = D × (0.95 ¥ LPF) × $0.10 

with the factors defined as follows: 

C = The charge in dollars to be assessed for 

any particular Demand Period of such 

month that the determination of power 

factor ‘‘PF’’ is calculated to be less than 

95 percent lagging. 

D = The Customer’s demand in kilowatts at 

the point of delivery for such Demand 

Period in which a low power factor was 

calculated. 

LPF = The lagging power factor, if any, 

determined by the formula ‘‘PF’’ for such 

Demand Period. 

If C is negative, then C = zero (0). 

3.3.4. Applicability of Power Factor 

Penalty 

The Power Factor Penalty is 

applicable to radial interconnections 

with the System of Southwestern. The 

total Power Factor Penalty for any 

month shall be the sum of all charges 

‘‘C’’ for all Demand Periods of such 

month. No penalty is assessed for 

leading power factor. Southwestern, in 

its sole judgment and at its sole option, 

may determine whether power factor 

calculations should be applied to (i) a 

single physical point of delivery, (ii) a 

combination of physical points of 

delivery where a Customer has a single, 

electrically integrated load, (iii) or 

interconnections. The general criteria 

for such decision shall be that, given the 

configuration of the Customer’s and 

Southwestern’s systems, Southwestern 

will determine, in its sole judgment and 

at its sole option, whether the power 

factor calculation more accurately 

assesses the detrimental impact on 

Southwestern’s system when the above 

formula is calculated for a single 

physical point of delivery, a 

combination of physical points of 

delivery, or for an interconnection as 

specified by an Interconnection 

Agreement. 

Southwestern, at its sole option, may 

reduce or waive Power Factor Penalties 

when, in Southwestern’s sole judgment, 

low power factor conditions were not 

detrimental to the System of 

Southwestern due to particular loading 

and voltage conditions at the time the 

power factor dropped below 95 percent 

lagging. 

4. Non-Federal Transmission/ 

Interconnection Facilities Service 

Miscellaneous Rates, Terms, and 

Conditions 

4.1. Real Power Losses 

Customers are required to self-provide 

all Real Power Losses for non-Federal 

energy transmitted by Southwestern on 

behalf of such Customers under the 

provisions detailed below. 

Real Power Losses are computed as 

four (4) percent of the total amount of 

non-Federal energy transmitted by 

Southwestern. The Customer’s monthly 

Real Power Losses are computed each 

month on a megawatthour basis as 

follows: 

ML = 0.04 × NFE 

with the factors defined as follows: 

ML = The total monthly loss energy, rounded 

to the nearest megawatthour, to be 

scheduled by a Customer for receipt by 

Southwestern for Real Power Losses 

associated with non-Federal energy 

transmitted on behalf of such Customer; 

and 

NFE = The amount of non-Federal energy 

that was transmitted by Southwestern on 

behalf of a Customer during a particular 

month. 

The Customer must schedule or cause 

to be scheduled to Southwestern, Real 

Power Losses for which it is responsible 

subject to the following conditions: 

4.1.1. The Customer shall schedule 

and deliver Real Power Losses back to 

Southwestern during the second month 

after they were incurred by 

Southwestern in the transmission of the 

Customer’s non-Federal power and 

energy over the System of Southwestern 

unless such Customer has accounted for 

Real Power Losses as part of a metering 

arrangement with Southwestern. 

4.1.2. On or before the twentieth day 

of each month, Southwestern shall 

determine the amount of non-Federal 

loss energy it provided on behalf of the 

Customer during the previous month 

and provide a written schedule to the 

Customer setting forth hour-by-hour the 

quantities of non-Federal energy to be 

delivered to Southwestern as losses 

during the next month. 

4.1.3. Real Power Losses not delivered 

to Southwestern by the Customer, 

according to the schedule provided, 

during the month in which such losses 


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PF= (kWh)+ ✓ (kWh2 + rkVAh2) 
Federal Register / Vol. 86, No. 175 / Tuesday, September 14, 2021 / Notices 51155 

1Supersedes Rate Schedule EE–11. 

** Extended through September 30, 2023, by 

approval of Rate Order No. SWPA–77 by the 

Administrator, Southwestern Power 

Administration. 

are due shall be billed by Southwestern 

to the Customer to adjust the end-ofmonth loss energy balance to zero (0) megawatthours and the Customer shall 

be obliged to purchase such energy at 

the following rates: 

Months associated with charge Rate per 

kilowatthour 

March, April, May, October, November, December ............................................................................................................................ $0.15 

January, February, June, July, August, September ............................................................................................................................ 0.30 

4.1.4. Real Power Losses delivered to 

Southwestern by the Customer in excess 

of the losses due during the month shall 

be purchased by Southwestern from the 

Customer at a rate per megawatthour 

equal to Southwestern’s rate per 

megawatthour for Supplemental 

Peaking Energy, as set forth in 

Southwestern’s then-effective Rate 

Schedule for Hydro Peaking Power to 

adjust such hourly end-of-month loss 

energy balance to zero (0) 

megawatthours. 

UNITED STATES DEPARTMENT OF 

ENERGY 

SOUTHWESTERN POWER 

ADMINISTRATION 

RATE SCHEDULE EE–13 1 ** 

WHOLESALE RATES FOR EXCESS 

ENERGY 

Effective: During the period October 1, 

2013, through September 30, 2021,** in 

accordance with the Federal Energy 

Regulatory Commission (FERC) order 

issued in Docket No. EF14–1–000 (Jan. 

9, 2014), extension approved by the 

Deputy Secretary in Docket No. EF14– 

1–002 (Sept. 13, 2017), extension 

approved by Assistant Secretary for 

Electricity in Rate Order No. 74 (Sept. 

22, 2019), and extension approved by 

the Administrator in Rate Order No. 77 

(August 30, 2021). 

Available: In the marketing area of 

Southwestern Power Administration 

(Southwestern), described generally as 

the States of Arkansas, Kansas, 

Louisiana, Missouri, Oklahoma, and 

Texas. 

Applicable: To electric utilities 

which, by contract, may purchase 

Excess Energy from Southwestern. 

Character and Conditions of Service: 

Three-phase, alternating current, 

delivered at approximately 60 Hertz, at 

the nominal voltage(s) and at the 

point(s) of delivery specified by 

contract. 

1. Wholesale Rates, Terms, and 

Conditions for Excess Energy 

Excess Energy will be furnished at 

such times and in such amounts as 

Southwestern determines to be 

available. 

1.2. Transmission and Related Ancillary 

Services 

Transmission service for the delivery 

of Excess Energy shall be the sole 

responsibility of such customer 

purchasing Excess Energy. 

1.3. Excess Energy Charge 

$0.0094 per kilowatthour of Excess 

Energy delivered. 

[FR Doc. 2021–19718 Filed 9–13–21; 8:45 am] 

BILLING CODE 6450–01–P 

ENVIRONMENTAL PROTECTION 

AGENCY 

[EPA–HQ–OW–2021–0547; FRL–5601.5–01– 

OW] 

RIN 2040–ZA38 

Preliminary Effluent Guidelines 

Program Plan 15 

AGENCY: Environmental Protection 

Agency (EPA). 

ACTION: Notice of availability. 

SUMMARY: This notice announces the 

availability of the U.S. Environmental 

Protection Agency’s (EPA) Preliminary 

Effluent Guidelines Program Plan 15 

(Preliminary Plan 15) and solicits public 

comment. The Clean Water Act (CWA) 

requires the EPA to biennially publish 

a plan for new and revised effluent 

limitations guidelines, after public 

review and comment. Preliminary Plan 

15 discusses EPA’s 2020 annual review 

of effluent limitations guidelines and 

pretreatment standards, presents the 

agency’s preliminary review of specific 

categories identified through the review, 

provides an update on the analyses and 

tools that EPA is continuing to develop, 

and discusses several new and ongoing 

rulemaking actions. 

DATES: Comments must be received on 

or before October 14, 2021. 

ADDRESSES: Submit your comments, 

identified by Docket ID No. EPA–HQ– 

OW–2021–0547, to the Federal 

eRulemaking Portal: http://

www.regulations.gov. Follow the online 

instructions for submitting comments. 

Once submitted, comments cannot be 

edited or withdrawn. EPA may publish 

any comment received to its public 

docket. Do not submit electronically any 

information you consider to be 

Confidential Business Information (CBI) 

or other information whose disclosure is 

restricted by statute. Multimedia 

submissions (audio, video, etc.) must be 

accompanied by a written comment. 

The written comment is considered the 

official comment and should include 

discussion of all points you wish to 

make. EPA will generally not consider 

comments or comment contents located 

outside of the primary submission (i.e. 

on the web, cloud, or other file sharing 

system). For additional submission 

methods, the full EPA public comment 

policy, information about CBI and 

multimedia submissions, and general 

guidance on making effective 

comments, please visit http://

www.epa.gov/dockets/commenting-epadockets. 

FOR FURTHER INFORMATION CONTACT: Dr. 

Phillip Flanders, Engineering and 

Analysis Division, Office of Water, 

4303T, U.S. Environmental Protection 

Agency, 1200 Pennsylvania Avenue 

NW, Washington, DC 20460; telephone 

number: (202) 566–8323; fax number: 

(202) 566–1053; email address: 

flanders.phillip@epa.gov. 

SUPPLEMENTARY INFORMATION: 

I. General Information 

A. Supporting Documents 

A key document providing additional 

information is the Preliminary Effluent 

Guidelines Program Plan 15 document. 

Supporting documents providing 

further details are also available for 

review. 

B. How can I get copies of these 

documents and other related 

information? 

1. Docket. The EPA has established an 

official public docket for these actions 

under Docket ID No. EPA–HQ–OW– 

2021–0547. The official public docket is 

the collection of materials that are 

available for public viewing at the Water 


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