44772 Federal Register / Vol. 82, No. 185 / Tuesday, September 26, 2017 / Notices 

eSubscription link on the Web site that 

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to a subscribed docket(s). For assistance 

with any FERC Online service, please 

email FERCOnlineSupport@ferc.gov, or 

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Comment Date: 5:00 p.m. Eastern time 

on October 19, 2017. 

Dated: September 19, 2017. 

Kimberly D. Bose, 

Secretary. 

[FR Doc. 2017–20478 Filed 9–25–17; 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. 

SUMMARY: The Deputy Secretary has 

approved and placed into effect on an 

interim basis Rate Order No. SWPA–72 

which extends the existing rate 

schedules for the Integrated System: 

Rate Schedule P–13, Wholesale Rates 

for Hydro Peaking Power 

Rate Schedule NFTS–13A, Wholesale 

Rates for Non-Federal Transmission 

Service 

Rate Schedule EE–13, Wholesale Rates 

for Excess Energy 

This is an interim rate action effective 

October 1, 2017, extending for a period 

of two years through September 30, 

2019. 

DATES: The effective period for the rate 

schedules specified in Rate Order No. 

SWPA–72 is October 1, 2017, through 

September 30, 2019. 

FOR FURTHER INFORMATION CONTACT: Mr. 

Marshall Boyken, Senior Vice President, 

Chief Operating Office, Office of 

Corporate Operations, Southwestern 

Power Administration, U.S. Department 

of Energy, One West Third Street, Tulsa, 

Oklahoma 74103, (918) 595–6646, 

marshall.boyken@swpa.gov or facsimile 

transmission (918) 595–6646. 

SUPPLEMENTARY INFORMATION: Pursuant 

to Delegation Order Nos. 00–037.00B, 

effective November 19, 2016, and 00– 

001.00F, effective November 17, 2014, 

and pursuant to the implementation 

authorities in 10 CFR 903.22(h) and 

903.23(a)(3), Rate Order No. SWPA–72 

is approved and placed into effect on an 

interim basis for the period October 1, 

2017, through September 30, 2019, for 

the following rate schedules: 

Rate Schedule P–13, Wholesale Rates 

for Hydro Peaking Power 

Rate Schedule NFTS–13A, Wholesale 

Rates for Non-Federal Transmission 

Service 

Rate Schedule EE–13, Wholesale Rates 

for Excess Energy 

These current rate schedules for the 

Integrated System were confirmed and 

approved on a final basis by the Federal 

Energy Regulatory Commission (FERC) 

on January 9, 2014, for the period 

October 1, 2013, through September 30, 

2017. Since initial FERC approval, a 

new section within rate schedule 

NFTS–13 was added to change from a 

stated rate to a revenue-requirement 

based methodology to better align with 

practices utilized by the Southwest 

Power Pool, Inc. Regional Transmission 

Organization. The revised rate schedule 

NFTS–13 was designated NFTS–13A 

and was subsequently approved on a 

final basis by FERC on March 9, 2017 

in Docket No. EF14–1–001 (158 FERC 

¶ 62,182) effective through September 

30, 2017. 

The Administrator, Southwestern, 

completed an annual review of the 

continuing adequacy of the existing 

hydroelectric rate schedules for the 

Integrated System. This review, as 

presented in the 2017 Power Repayment 

Studies (PRSs), indicated the need for a 

revenue adjustment of 0.7 percent to 

continue to satisfy cost recovery criteria. 

Because the 0.7 percent revenue 

adjustment was within Southwestern’s 

established ±2 percent rate adjustment 

threshold, the Administrator deferred 

the revenue adjustment and now adopts 

the two-year extension of the Integrated 

System rate schedules. 

The Administrator has followed Title 

10, part 903 subpart A, of the Code of 

Federal Regulations, ‘‘Procedures for 

Public Participation in Power and 

Transmission Rate Adjustments and 

Extensions’’ for the proposed extension 

to the rate schedules. The public was 

advised by notice published in the 

Federal Register (82 FR 27062), June 13, 

2017, of the proposed extension of the 

rate schedules and of the opportunity to 

provide written comments for a period 

of 30 days ending July 13, 2017. No 

comments were received. 

Information regarding the extension of 

these rate schedules, including the rate 

schedules and other supporting 

material, is available for public review 

in the offices of Southwestern Power 

Administration, Williams Tower I, One 

West Third Street, Tulsa, Oklahoma 

74103. I have reviewed the 

Southwestern proposal and I approve 

Rate Order No. SWPA–72. 

Dated: September 13, 2017. 

Dan Brouillette, 

Deputy Secretary. 

UNITED STATES OF AMERICA 

DEPARTMENT OF ENERGY 

DEPUTY SECRETARY 

In the matter of: Southwestern Power 

Administration Integrated System Rates 

Rate Order No. SWPA–72 

ORDER APPROVING EXTENSION OF RATE 

SCHEDULES ON AN INTERIM BASIS 

Pursuant to Sections 302(a) and 301(b) of 

the Department of Energy Organization Act, 

Public Law 95–91, 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, 

the Secretary of Energy delegated to the 

Administrator, Southwestern, the authority 

to develop power and transmission rates, 

delegated to the Deputy Secretary of Energy 

the authority to confirm, approve, and place 

in effect such rates on an interim basis and 

delegated to the Federal Energy Regulatory 

Commission (FERC) the authority to confirm 

and approve on a final basis or to disapprove 

rates developed by the Administrator under 

the delegation. Pursuant to that delegated 

authority, the Deputy Secretary 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, for the period October 1, 2013, 

through September 30, 2017. 

Rate Schedule P–13, Wholesale Rates for 

Hydro Peaking Power 

Rate Schedule NFTS–13A, Wholesale Rates 

Non-Federal Transmission Service 

Rate Schedule EE–13, Wholesale Rate for 

Excess Energy 

Since initial FERC approval, a new section 

within rate schedule NFTS–13 was added to 

change from a stated rate to a revenuerequirement based methodology to better 

align with practices utilized by the 

Southwest Power Pool, Inc. Regional 

Transmission Organization. The revised rate 

schedule NFTS–13 was designated NFTS– 

13A and was subsequently approved on a 

final basis by FERC on March 9, 2017 in 

Docket No. EF14–1–001 (158 FERC ¶ 62,182) 

effective through September 30, 2017. 

Southwestern followed Title 10 Part 903 of 

the Code of Federal Regulations, ‘‘Procedures 

for Public Participation in Power and 

Transmission Rate Adjustments and 

Extensions’’ (Part 903) 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 13, 

2017, (82 FR 27062), with written comments 

due by July 13, 2017. No comments were 

received. 

Federal Register / Vol. 82, No. 185 / Tuesday, September 26, 2017 / Notices 44773 

1Supersedes Rate Schedule P–11. 

** Extended through September 30, 2019 by 

approval of Rate Order No. SWPA–72 by the Deputy 

Secretary of Energy. 

DISCUSSION 

The existing Integrated System rate 

schedules are based on the 2013 Power 

Repayment Studies (PRSs). PRSs have been 

completed on the Integrated System each 

year since approval of the existing rate 

schedules. The estimated revised annual 

revenue identified by the PRSs since the 

2013 PRSs have indicated the need for 

minimal rate increases. Since the revenue 

changes reflected by the PRSs were within 

the plus-or-minus two percent rate 

adjustment threshold established by the 

Administrator on June 23, 1987, these rate 

adjustments were deferred in the best interest 

of the government. 

The 2017 PRSs indicated the need for an 

annual revenue increase of 0.7 percent. As 

has been the case since the existing rate 

schedules were approved, the 2017 rate 

adjustment fell within Southwestern’s plusor-minus two percent rate adjustment 

threshold and was deferred by the 

Administrator with no rate filing necessary. 

However, the existing rate schedules are set 

to expire on September 30, 2017. 

Consequently, Southwestern proposes to 

extend the existing rate schedules for a twoyear period ending September 30, 2019, on 

an interim basis under the implementation 

authorities noted in 10 CFR 903.22(h) and 

903.23(a)(3). 

COMMENTS AND RESPONSES 

Southwestern received no comments 

regarding the extension of the Integrated 

System 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. 

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 2017 

Integrated System PRSs indicate the need for 

an annual revenue increase of 0.7 percent. 

However, the 2017 rate adjustment falls 

within Southwestern’s established plus-orminus two percent rate adjustment threshold 

and was deferred. Southwestern’s 2018 PRSs 

will determine the appropriate level of 

revenues needed for the next rate period. In 

accordance with Delegation Order Nos. 00– 

037.00B (November 19, 2016), and 00– 

001.00F, effective November 17, 2014, and 

Section 5 of the Flood Control Act of 1944, 

the Administrator has determined that the 

existing Integrated System rate schedules are 

the lowest possible rates consistent with 

sound business principles, and their 

extension is consistent with applicable law. 

ENVIRONMENT 

The Southwestern NEPA Compliance 

Officer determined that this class of actions 

is categorically excluded from the 

requirements of preparing either an 

Environmental Impact Statement or an 

Environmental Assessment. No additional 

evaluation of the environmental impact of 

the extension of the existing rate schedules 

was conducted since no change in 

anticipated revenues has been made to the 

currently-approved Integrated System rate 

schedules. 

ADMINISTRATIVE PROCEDURES 

The Administrative Procedure Act (5 

U.S.C. 553(d)) prescribes that the required 

publication or service of a substantive rule 

shall 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 Department 

of Energy finds good cause to waive the 30- 

day delay in 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 

the authority delegated to me by the 

Secretary of Energy, I hereby extend on an 

interim basis, for the period of two years, 

effective October 1, 2017, through September 

30, 2019, the current rate schedules for the 

Integrated System: 

Rate Schedule P–13, Wholesale Rates for 

Hydro Peaking Power 

Rate Schedule NFTS–13A, Wholesale Rates 

for Non-Federal Transmission Service 

Rate Schedule EE–13, Wholesale Rates for 

Excess Energy 

Dated: September 17, 2017 

lllllllllllllllllllll

Dan Brouillette, 

Deputy Secretary. 

UNITED STATES DEPARTMENT OF 

ENERGY 

SOUTHWESTERN POWER 

ADMINISTRATION 

RATE SCHEDULE P–13 1

** 

WHOLESALE RATES FOR HYDRO 

PEAKING POWER 

Effective: 

During the period October 1, 2013, through 

September 30, 2019**, in accordance with 

Federal Energy Regulatory Commission order 

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

000. 

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 

1.2. 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: 

1.2.1. Scheduling, System Control, and 

Dispatch Service 

is provided by Southwestern as Balancing 

Authority Area operator and is in regard to 

interchange and load-match scheduling and 

related system control and dispatch 

functions. 

1.2.2. 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. 

1.2.3. 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-by-moment changes in load and to 

maintain frequency within a Balancing 

Authority Area. 

1.2.4. 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. 

1.2.5. 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. 

1.2.6. 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 

44774 Federal Register / Vol. 82, No. 185 / Tuesday, September 26, 2017 / Notices 

a contractual arrangement between the 

parties. 

1.3. Customer 

The entity which is utilizing and/or 

purchasing Federal Power and Federal 

Energy and services from Southwestern 

pursuant to this Rate Schedule. 

1.4. 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. 

1.5. Federal Power and Energy 

The power and energy provided from the 

System of Southwestern. 

1.6. 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. 

1.7. Peaking Billing Demand 

The quantity equal to the Peaking Contract 

Demand for any month unless otherwise 

provided by the Customer’s Power Sales 

Contract. 

1.8. 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. 

1.9. 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. 

1.10. 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. 

2.2. Hydro Peaking Power Rates, Terms, and 

Conditions 

2.2.1. Monthly Capacity Charge for Hydro 

Peaking Power 

$4.50 per kilowatt of Peaking Billing 

Demand. 

2.2.2. 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. 

2.2.3. 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: 

2.2.3.1. 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; 

2.2.3.2. The non-Federal energy 

transmitted under such secondary service is 

delivered to the Customer’s point of delivery 

for Hydro Peaking Power; 

2.2.3.3. The Customer commits to provide 

Real Power Losses associated with such 

deliveries of non-Federal energy; and 

2.2.3.4. 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. 

2.2.4. 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. 

2.3. Peaking Energy and Supplemental 

Peaking Energy Rates, Terms, and 

Conditions 

2.3.1. 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. 

2.3.2. Supplemental Energy Charge 

$0.0094 per kilowatthour of Supplemental 

Peaking Energy delivered. 

2.3.3. 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. 

2.3.3.1. 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’’). 

2.3.3.2. 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 

Federal Register / Vol. 82, No. 185 / Tuesday, September 26, 2017 / Notices 44775 

1The average annual use of energy from storage 

for Regulation and Frequency Response Service is 

based on Southwestern studies. 

up to a total of ±$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 kilowatthour, 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 kilowatthour 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. 

2.4. Transformation Service Rates, Terms, 

and Conditions 

2.4.1. 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. 

2.4.2. 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. 

2.5. Ancillary Services Rates, Terms, and 

Conditions 

2.5.1. Capacity Charges for Ancillary 

Services 

2.5.1.1. 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. 

2.5.1.2. Spinning Operating Reserve Service 

Monthly rate of $0.0146 per kilowatt of 

Peaking Billing Demand. 

Daily rate of $0.00066 per kilowatt for nonFederal generation inside Southwestern’s 

Balancing Authority Area. 

2.5.1.3. Supplemental Operating Reserve 

Service 

Monthly rate of $0.0146 per kilowatt of 

Peaking Billing Demand. 

Daily rate of $0.00066 per kilowatt for nonFederal generation inside Southwestern’s 

Balancing Authority Area. 

2.5.1.4. Energy Imbalance Service 

$0.0 per kilowatt for all reservation periods. 

2.5.2. 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. 

2.5.3. 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. 

2.5.4. 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. 

2.5.5. 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. 

44776 Federal Register / Vol. 82, No. 185 / Tuesday, September 26, 2017 / Notices 

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. 

2.5.5.1. 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–13, 

then it shall not be applied here. 

2.5.5.2. 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. 

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 noncoincident basis and shall be calculated for 

the Customer from their highest metered load 

plus generation behind the meter. 

2.5.6. 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 Non-Federal 

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 

3.2. Capacity Overrun Penalty 

3.2.1. 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 

3.2.2. 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. 

3.3. Energy Overrun Penalty 

3.3.1. Penalty Charge for Energy Overrun 

$0.1034 per kilowatthour for each 

kilowatthour of overrun. 

3.3.2. 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. 

3.4. Power Factor Penalty 

3.4.1. 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. 

3.4.2. 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. 

3.4.3. 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 


EN26SE17.000</GPH>
Federal Register / Vol. 82, No. 185 / Tuesday, September 26, 2017 / Notices 44777 

1Supersedes Rate Schedule NFTS–13. 

** Extended through September 30, 2019 by 

approval of Rate Order No. SWPA–72 by the Deputy 

Secretary of Energy. 

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). 

3.4.4. 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 

4.2. 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: 

4.2.1. 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. 

4.2.2. 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 hourby-hour the quantities of non-Federal energy 

to be delivered to Southwestern as losses 

during the next month. 

4.2.3. 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-of-month 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 

4.2.4. 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 NFTS–13 1 ** 

WHOLESALE RATES FOR NON-FEDERAL 

TRANSMISSION/INTERCONNECTION 

FACILITIES SERVICE 

Effective 

During the period January 1, 2017, through 

September 30, 2019 **, in accordance with 

Federal Energy Regulatory Commission order 

issued March 9, 2017, Docket No. EF14–1– 

001. 

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 

1.2. 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: 

1.2.1. Scheduling, System Control, and 

Dispatch Service 

is provided by Southwestern as Balancing 

Authority Area operator and is in regard to 

interchange and load-match scheduling and 

related system control and dispatch 

functions. 

44778 Federal Register / Vol. 82, No. 185 / Tuesday, September 26, 2017 / Notices 

1.2.2. 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. 

1.2.3. 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-by-moment changes in load and to 

maintain frequency within a Balancing 

Authority Area. 

1.2.4. 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. 

1.2.5. 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. 

1.2.6. 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. 

1.3. Customer 

The entity which is utilizing and/or 

purchasing services from Southwestern 

pursuant to this Rate Schedule. 

1.4. 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. 

1.5. 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. 

1.6. 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. 

1.7. 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. 

1.8. 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. 

1.9. 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. 

1.10. 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. 

1.11. 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. 

1.12. Secondary Transmission Service 

Service that is associated with Firm Point-toPoint Transmission Service and Network 

Integration Transmission Service. For Firm 

Point-to-Point Transmission Service, it 

consists of transmission service provided on 

an as-available, 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 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. 

1.13. Service Agreement 

A contract executed between a Customer and 

Southwestern for the transmission of nonFederal power and energy over the System of 

Southwestern or for interconnections which 

include the following: 

1.13.1. Firm Transmission Service 

Agreement 

provides for reserved transmission capacity 

on a firm basis, for a particular point-to-point 

delivery path. 

1.13.2. 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. 

1.13.3. 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. 

1.13.4. Non-Firm Transmission Service 

Agreement 

provides for the Customer to request 

transmission service on a non-firm basis. 

1.14. Service Request 

The request made under a Transmission 

Service Agreement through the Southwest 

Power Pool, Inc. (hereinafter ‘‘SPP’’) Open 

Access Same-Time Information System 

(hereinafter ‘‘OASIS’’) for reservation of 

transmission capacity over a particular pointto-point delivery path for a particular period. 

The Customer must submit hourly schedules 

for actual service in addition to the Service 

Request. 

1.15. 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. 

1.16. Transmission Service Transaction 

A Service Request that has been approved by 

SPP. 

1.17. 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 Point-to-Point Transmission 

Service, Network Integration Transmission 

Service, and Interconnection Facilities 

Service 

2.2. Firm Point-to-Point Transmission 

Service Rates, Terms, and Conditions 

2.2.1. 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. 

2.2.2. 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. 

Federal Register / Vol. 82, No. 185 / Tuesday, September 26, 2017 / Notices 44779 

2.2.3. Daily Capacity Charge for Firm Pointto-Point Transmission Service 

$0.0673 per kilowatt of transmission capacity 

reserved in increments of one day of service. 

2.2.4. Services Associated with Capacity 

Charge for Firm Point-to-Point Transmission 

Service 

The capacity charge for Firm Point-to-Point 

Transmission Service includes Secondary 

Transmission Service, but does not include 

charges for Ancillary Services associated 

with actual schedules. 

2.2.5. Applicability of Capacity Charge for 

Firm Point-to-Point Transmission Service 

Capacity charges for Firm Point-to-Point 

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. 

2.3. Non-Firm Point-to-Point Transmission 

Service Rates, Terms, and Conditions 

2.3.1. 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. 

2.3.2. Weekly Capacity Charge for Non-Firm 

Point-to-Point Transmission Service 

80 percent of the monthly capacity charge 

divided by 4 for Firm Point-to-Point 

Transmission Service reserved in increments 

of one week. 

2.3.3. Daily Capacity Charge for Non-Firm 

Point-to-Point Transmission Service 

80 percent of the monthly capacity charge 

divided by 22 for Firm Point-to-Point 

Transmission Service reserved in increments 

of one day. 

2.3.4. Hourly Capacity Charge for Non-Firm 

Point-to-Point Transmission Service 

80 percent of the monthly capacity charge 

divided by 352 for Firm Point-to-Point 

Transmission Service reserved in increments 

of one hour. 

2.3.5. Applicability of Charges for Non-Firm 

Point-to-Point Transmission Service 

Capacity charges for Non-Firm Point-to-Point 

Transmission Service are applied to 

quantities reserved under a Transmission 

Service Transaction, and do not include 

charges for Ancillary Services. 

2.4. Network Integration Transmission 

Service Rates, Terms, and Conditions 

2.4.1. Annual Revenue Requirement for 

Network Integration Transmission Service 

$15,533,800. 

2.4.2. Monthly Revenue Requirement for 

Network Integration Transmission Service 

$1,294,483. 

2.4.3. Net Capacity Available for Network 

Integration Transmission Service 

872,000 kilowatts. 

2.4.4. Monthly Capacity Charge for Network 

Integration Transmission Service 

$1.48 per kilowatt of Network Load (charge 

derived from $1,294,483 ÷ 872,000 

kilowatts). 

2.4.5. 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. 

2.4.6. 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. 

2.5. Interconnection Facilities Service Rates, 

Terms, and Conditions 

2.5.1. Monthly Capacity Charge for 

Interconnection Facilities Service 

$1.48 per kilowatt. 

2.5.2. 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. 

2.6. Transformation Service Rates, Terms, 

and Conditions 

2.6.1. 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. 

2.6.2. 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. 

44780 Federal Register / Vol. 82, No. 185 / Tuesday, September 26, 2017 / Notices 

1The average annual use of energy from storage 

for Regulation and Frequency Response Service is 

based on Southwestern studies. 

2.7. Ancillary Services Rates, Terms, and 

Conditions 

2.7.1. Capacity Charges for Ancillary 

Services 

2.7.1.1. 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 Long-Term 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 non-firm 

transmission service. 

2.7.1.2. 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 Long-Term Firm 

Transmission Service Agreement or Network 

Transmission Service Agreement. 

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 non-firm 

transmission service. 

2.7.1.3. 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 Long-Term 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 non-firm 

transmission service plus the Regulation 

Purchased Adder as defined in Section 2.6.5 

of this Rate Schedule. 

2.7.1.4. 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 Long-Term 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 non-firm 

transmission service. 

2.7.1.5. 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 Long-Term 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 non-firm 

transmission service. 

2.7.1.6. Energy Imbalance Service 

$0.0 per kilowatt for all reservation periods. 

2.7.2. 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. 

2.7.3. 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. 

2.7.4. 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. 

2.7.5. 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 

Federal Register / Vol. 82, No. 185 / Tuesday, September 26, 2017 / Notices 44781 

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. 

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. 

2.7.5.1. 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. 

2.7.5.2. 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. 

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 2.6.5, 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 noncoincident basis and shall be calculated for 

the Customer from their highest metered load 

plus generation behind the meter. 

2.7.6. Energy Imbalance Service Limitations 

Energy Imbalance Service is authorized for 

use only within a bandwidth of ± 1.5 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 ± 1.5 percent, but 

which are less than ± 2,000 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 

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 

44782 Federal Register / Vol. 82, No. 185 / Tuesday, September 26, 2017 / Notices 

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 

4.2. 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: 

4.2.1. 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. 

4.2.2. 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 hourby-hour the quantities of non-Federal energy 

to be delivered to Southwestern as losses 

during the next month. 

4.2.3. 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-of-month 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 

4.2.4. 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. 


EN26SE17.001</GPH>
Federal Register / Vol. 82, No. 185 / Tuesday, September 26, 2017 / Notices 44783 

1Supersedes Rate Schedule EE–11. 

** Extended through September 30, 2019 by 

approval of Rate Order No. SWPA–72 by the Deputy 

Secretary of Energy. 

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, 2019 **, in accordance with 

Federal Energy Regulatory Commission order 

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

000. 

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. 

1.1. Transmission and Related Ancillary 

Services 

Transmission service for the delivery of 

Excess Energy shall be the sole responsibility 

of such customer purchasing Excess Energy. 

1.2. Excess Energy Charge 

$0.0094 per kilowatthour of Excess Energy 

delivered. 

[FR Doc. 2017–20034 Filed 9–25–17; 8:45 am] 

BILLING CODE 6450–01–P 

ENVIRONMENTAL PROTECTION 

AGENCY 

[FRL–9968–18–OP] 

EPA Smart Sectors Program Launch 

AGENCY: Environmental Protection 

Agency (EPA). 

ACTION: Notice. 

SUMMARY: The U.S. Environmental 

Protection Agency (EPA) is announcing 

the Smart Sectors program in the Office 

of Policy. Based on the successful EPA 

Sector Strategies program, EPA’s Smart 

Sectors program will re-examine how 

EPA engages with industry in order to 

reduce unnecessary regulatory burden, 

create certainty and predictability, and 

improve the ability of both EPA and 

industry to conduct long-term 

regulatory planning while also 

protecting the environment and public 

health. 

FOR FURTHER INFORMATION CONTACT: 

Daisy Letendre, Senior Advisor for 

Policy and Strategic Communications, 

Office of Policy, Office of Administrator, 

Environmental Protection Agency, Mail 

Code: 1104A, 1200 Pennsylvania Ave. 

NW., Washington, DC 200460; 

telephone number: (202) 564–0410; 

email address: sectors@epa.gov. 

SUPPLEMENTARY INFORMATION:

General Information 

EPA has initially identified the 

following sectors to work with: 

Aerospace; agriculture; automotive; 

cement and concrete; chemical 

manufacturing; construction; electronics 

and technology; iron and steel; oil and 

gas; ports and shipping; and utilities 

and power generation. Sectors were 

selected based on each sector’s potential 

to improve the environment and public 

health. EPA welcomes participation 

from other stakeholders. 

The Smart Sectors program will 

designate staff-level points of contact 

who are highly knowledgeable about 

specific industries. These individuals 

will act as liaisons among industry trade 

associations and companies, EPA 

program and regional offices, state and 

local governments, and other 

stakeholder groups. The sector liaisons 

will focus their attention primarily on 

three main areas: Building relationships 

and improving customer service to 

sectors; developing additional expertise 

in each industry’s operations and 

environmental performance; and 

informing the planning of future 

policies, regulations, and Agency 

processes. 

EPA anticipates that participating 

industries will benefit from coordinated, 

cooperative, and constructive problemsolving with government. The Agency 

will invite participating industries to 

engage in active dialogue and offer their 

own innovative ideas to reduce 

environmental impacts. Because 

industry-wide environmental 

performance improvement is the goal, 

EPA will work with trade associations 

and others to find creative ways to 

document environmental progress and 

burden reductions. 

Dated: September 14, 2017. 

Samantha K. Dravis, 

Associate Administrator for Policy. 

[FR Doc. 2017–20310 Filed 9–25–17; 8:45 am] 

BILLING CODE 6560–50–P 

ENVIRONMENTAL PROTECTION 

AGENCY 

[FRL–9968–08–OLEM] 

Access to Confidential Business 

Information by Eastern Research 

Group (ERG) 

AGENCY: Environmental Protection 

Agency (EPA). 

ACTION: Notice of access to data and 

request for comments. 

SUMMARY: EPA will authorize its 

contractor, Eastern Research Group 

(ERG) to access Confidential Business 

Information (CBI) which has been 

submitted to EPA under the authority of 

all sections of the Resource 

Conservation and Recovery Act (RCRA) 

of 1976, as amended. EPA has issued 

regulations that outline business 

confidentiality provisions for the 

Agency and require all EPA Offices that 

receive information designated by the 

submitter as CBI to abide by these 

provisions. 

DATES: Access to confidential data 

submitted to EPA will occur no sooner 

than October 6, 2017. 

FOR FURTHER INFORMATION CONTACT: 

LaShan Haynes, Document Control 

Officer, Office of Resource Conservation 

and Recovery, (5305P), U.S. 

Environmental Protection Agency, 1200 

Pennsylvania Avenue NW., Washington, 

DC 20460, 703–605–0516. 

SUPPLEMENTARY INFORMATION: 

1. Access to Confidential Business 

Information 

Under EPA Contract EP–W–10–055, 

entitled ‘‘Advancing SMM: Waste Facts 

and Figures and Related Tasks,’’ the 

Eastern Research Group (ERG) will 

assist the Office of Resource 

Conservation and Recovery, Resource 

Conservation and Sustainability 

Division in collecting and analyzing 

municipal solid waste (MSW) 

information. The contract addresses 

MSW and other waste such as 

construction and demolition debris, 

however, the confidential business 

information (CBI) only relates to the 

MSW information collected and 

analyzed in the contract. The contract 

period is from August 2017–February 

28, 2018. Some of the data collected 

from industry are claimed by industry to 

contain trade secrets or CBI. In