82880 Federal Register / Vol. 88, No. 226 / Monday, November 27, 2023 / Notices 

1Order Confirming and Approving Rate Schedule 

on a Final Basis, FERC Docket No. EF 22–1–000 

(179 FERC ¶ 62,085 (2022)). 2Order Confirming and Approving Rate Schedule 

on a Final Basis, FERC Docket No. EF 21–7–000 

(178 FERC ¶ 62,154 (2022)). 3Order Confirming and Approving Rate 

Schedules on a Final Basis, FERC Docket No. EF 

20–7–000 (173 FERC ¶ 61,230 (2020)). 

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. 

The Commission’s Office of Public 

Participation (OPP) supports meaningful 

public engagement and participation in 

Commission proceedings. OPP can help 

members of the public, including 

landowners, environmental justice 

communities, Tribal members and 

others, access publicly available 

information and navigate Commission 

processes. For public inquiries and 

assistance with making filings such as 

interventions, comments, or requests for 

rehearing, the public is encouraged to 

contact OPP at (202) 502–6595 or OPP@

ferc.gov. 

Dated: November 20, 2023. 

Debbie-Anne A. Reese, 

Deputy Secretary. 

[FR Doc. 2023–26072 Filed 11–24–23; 8:45 am] 

BILLING CODE 6717–01–P 

DEPARTMENT OF ENERGY 

Western Area Power Administration 

Salt Lake City Area Integrated Projects 

and Colorado River Storage Project— 

Rate Order No. WAPA–206 

AGENCY: Western Area Power 

Administration, DOE. 

ACTION: Notice of rate order concerning 

firm power fixed rates and transmission 

services, ancillary services, sale of 

surplus products, and joint dispatch 

transmission service formula rates. 

SUMMARY: The provisional fixed rates for 

the Salt Lake City Area Integrated 

Projects (SLCA/IP) firm power service 

and the formula rates for the Colorado 

River Storage Project (CRSP) 

transmission services, ancillary services, 

sale of surplus products, and joint 

dispatch transmission service have been 

confirmed, approved, and placed into 

effect on an interim basis. The firm 

power rates under SLCA/IP Firm Power 

Rate Schedule SLIP–F12 expire 

December 31, 2023. Western Area Power 

Administration’s (WAPA) CRSP 

Management Center (CRSP MC) is 

renewing all SLCA/IP and CRSP rates 

under one Federal Register notice 

(FRN), making all rates effective for the 

same period. These new rates replace 

existing firm power, transmission, 

ancillary services, sale of surplus 

products, and joint dispatch 

transmission service rates under Rate 

Orders No. WAPA–190, WAPA–195, 

and WAPA–199. 

DATES: The provisional rates under Rate 

Schedules SLIP–F13, SP–NW6, SP– 

PTP10, SP–NFT9, SP–UU3, SP–EI6, SP– 

SSR6, SP–SS2, and SP–NFJDT are 

effective on the first day of the first full 

billing period beginning on or after 

January 1, 2024, and will remain in 

effect through December 31, 2028, 

pending confirmation and approval by 

the Federal Energy Regulatory 

Commission (FERC) on a final basis or 

until superseded. Pursuant to 10 CFR 

903.21(b), the WAPA Administrator has 

set the effective date to align with the 

expiration of the existing rate. 

FOR FURTHER INFORMATION CONTACT: 

Rodney Bailey, CRSP Manager, 

Colorado River Storage Project 

Management Center, Western Area 

Power Administration, 1800 South Rio 

Grande Avenue, Montrose, CO 81401, 

970–252–3000, or email: CRSPMC-rateadj@wapa.gov; or Tamala Gheller, Rates 

Manager, Colorado River Storage Project 

Management Center, Western Area 

Power Administration, 970–240–6545, 

or email: CRSPMC-rate-adj@wapa.gov. 

SUPPLEMENTARY INFORMATION: On May 

12, 2022, FERC approved and confirmed 

Rate Schedule SLIP–F12 for Firm Power 

Service under Rate Order No. WAPA– 

199 on a final basis through December 

31, 2023.1 On March 18, 2022, FERC 

approved and confirmed Rate Schedule 

SP–NFJDT for Joint Dispatch 

Transmission Service under Rate Order 

No. WAPA–195 on a final basis through 

September 30, 2024.2 On December 17, 

2020, FERC approved and confirmed the 

following rate schedules under Rate 

Order No. WAPA–190 on a final basis 

through September 30, 2025: 3 SLIP–F11 

for Firm Power Service (superseded by 

SLIP–F12 under WAPA–199), SP–NW5 

for Network Integration Transmission 

Service, SP–PTP9 for Firm Point-toPoint Transmission Service, SP–NFT8 

for Non-Firm Point-to-Point 

Transmission Service, SP–UU2 for 

Unreserved Use Penalties, SP–E15 for 

Energy and Generation Imbalance, SP– 

SSR5 for Operating Reserves—Spinning 

and Supplemental Reserve Services, and 

SP–SS1 for Sale of Surplus Products. 

On June 22, 2023, Western Area 

Power Administration (WAPA) 

published a Federal Register notice 

(Proposal FRN) (88 FR 40813) proposing 

new 5-year rates for firm power service, 

transmission services, ancillary services, 

sale of surplus products, and joint 

dispatch transmission service. The 

Proposal FRN initiated a 90-day public 

consultation and comment period and 

set forth the date and location of the 

public information and the public 

comment forums. The firm power rate is 

a fixed rate. The transmission services, 

ancillary services, surplus products, and 

joint dispatch rates continue the 

formula-based methodology that 

includes an annual update to the 

financial and load data in the applicable 

rate formulas. The inputs into the 

formulas and resulting charges under 

the rates will be annually updated on 

October 1. 

On August 28, 2023, CRSP MC sent 

email notice to extend the Comment and 

Consultation Period for Proposed 

WAPA–206 from September 1, 2023, 

through October 3, 2023. The intent of 

this extension was to provide interested 

parties additional time to review and 

provide comments related to the results 

of the Bureau of Reclamation’s August 

24-month study data, along with other 

aspects of the rate proposal made 

available by WAPA during the original 

comment period. 

Legal Authority 

By Delegation Order No. S1–DEL– 

RATES–2016, effective November 19, 

2016, the Secretary of Energy delegated: 

(1) the authority to develop power and 

transmission rates to the WAPA 

Administrator; (2) the authority to 

confirm, approve, and place such rates 

into effect on an interim basis to the 

Deputy Secretary of Energy; and (3) the 

authority to confirm, approve, and place 

into effect on a final basis, or to remand 

or disapprove such rates, to FERC. By 

Delegation Order No. S1–DEL–S3–2023, 

effective April 10, 2023, the Secretary of 

Energy also delegated the authority to 

confirm, approve, and place such rates 

into effect on an interim basis to the 

Under Secretary for Infrastructure. By 

Redelegation Order No. S3–DEL– 

WAPA1–2023, effective April 10, 2023, 

the Under Secretary for Infrastructure 

further redelegated the authority to 

confirm, approve, and place such rates 


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Federal Register / Vol. 88, No. 226 / Monday, November 27, 2023 / Notices 82881 

4 50 FR 37835 (Sept. 18, 1985) and 84 FR 5347 

(Feb. 21, 2019). 

5This Act transferred to, and vested in, the 

Secretary of Energy the power marketing functions 

of the Secretary of the Department of the Interior 

and the Bureau of Reclamation (Reclamation) under 

the Reclamation Act of 1902 (ch. 1093, 32 Stat. 

388), as amended and supplemented by subsequent 

laws, particularly section 9(c) of the Reclamation 

Project Act of 1939 (43 U.S.C. 485h(c)) and other 

acts that specifically apply to the projects involved. 

6 50 FR 37835 (Sept. 18, 1985) and 84 FR 5347 

(Feb. 21, 2019). 

into effect on an interim basis to 

WAPA’s Administrator. This rate action 

is issued under Redelegation Order No. 

S3–DEL–WAPA1–2023 and Department 

of Energy procedures for public 

participation in rate adjustments set 

forth at 10 CFR part 903.4

Following DOE’s review of CRSP 

MC’s proposal, Rate Order No. WAPA– 

206, which provides the fixed rates for 

the SLCA/IP firm power service and the 

formula rates for the CRSP transmission 

services, ancillary services, sale of 

surplus products, and joint dispatch 

transmission service, is hereby 

confirmed, approved, and placed into 

effect on an interim basis. By this order, 

I may be placing the rates into effect in 

less than 30 days to meet contractual 

obligations and avoid financial 

difficulties. WAPA will submit Rate 

Order No. WAPA–206 to FERC for 

confirmation and approval on a final 

basis. 

DEPARTMENT OF ENERGY 

ADMINISTRATOR, WESTERN AREA 

POWER ADMINISTRATION 

In the Matter of: Western Area Power 

Administration Colorado River Storage 

Project Management Center Rate Adjustment 

for the Salt Lake City Area Integrated Projects 

Firm Power Rates and the Colorado River 

Storage Project Transmission Services, 

Ancillary Services, Sale of Surplus Products, 

and Joint Dispatch Transmission Service 

Rate Order No. WAPA–206 

Order Confirming, Approving, and 

Placing the Fixed Firm Power Rates for 

the Salt Lake City Area Integrated 

Projects and the Formula Rates for 

Transmission Services, Ancillary 

Services, Sale of Surplus Products, and 

Joint Dispatch Transmission Service for 

the Colorado River Storage Project Into 

Effect on an Interim Basis 

The rates in Rate Order No. WAPA– 

206 are established following section 

302 of the Department of Energy (DOE) 

Organization Act (42 U.S.C. 7152).5

By Delegation Order No. S1–DEL– 

RATES–2016, effective November 19, 

2016, the Secretary of Energy delegated: 

(1) the authority to develop power and 

transmission rates to the Western Area 

Power Administration (WAPA) 

Administrator; (2) the authority to 

confirm, approve, and place such rates 

into effect on an interim basis to the 

Deputy Secretary of Energy; and (3) the 

authority to confirm, approve, and place 

into effect on a final basis, or to remand 

or disapprove such rates, to the Federal 

Energy Regulatory Commission (FERC). 

By Delegation Order No. S1–DEL–S3– 

2023, effective April 10, 2023, the 

Secretary of Energy also delegated the 

authority to confirm, approve, and place 

such rates into effect on an interim basis 

to the Under Secretary for 

Infrastructure. By Redelegation Order 

No. S3–DEL–WAPA1–2023, effective 

April 10, 2023, the Under Secretary for 

Infrastructure further redelegated the 

authority to confirm, approve, and place 

such rates into effect on an interim basis 

to WAPA’s Administrator. This rate 

action is issued under Redelegation 

Order No. S3–DEL–WAPA1–2023 and 

DOE procedures for public participation 

in rate adjustments set forth at 10 CFR 

part 903.6

Acronyms, Terms, and Definitions 

As used in this Rate Order, the 

following acronyms, terms, and 

definitions apply: 

Basin Fund: Upper Colorado River 

Basin Fund—a revolving fund that 

operates without annual appropriations. 

Capacity: The electric capability of a 

generator, transformer, transmission 

circuit, or other equipment. It is 

expressed in kilowatts (kW). 

Capacity Rate: The rate which sets 

forth the charges for capacity. It is 

expressed in $/kWmonth and applied to 

each kW delivered to each Customer. 

CRC: Cost Recovery Charge—an 

additional surcharge on all SHP energy 

deliveries, which are long-term energy 

sales provided under WAPA’s SLCA/IP 

firm electric service contracts. 

CRCM: The North American Electric 

Reliability Corporation (NERC)- 

registered Joint Dispatch Transmission 

Service Provider for WAPA’s Colorado 

River Storage Project Management 

Center (CRSP MC) transmission 

facilities included in the Transmission 

System within the Western Energy 

Imbalance Service (WEIS) Market 

Footprint. 

CROD: Contract Rate of Delivery—the 

maximum amount of capacity made 

available to a Preference Customer for a 

period specified under a contract. 

CRMMS: Colorado River Mid-term 

Modeling System—one of two river 

system models developed and 

maintained by Reclamation to support 

operational decision-making and 

planning for the Colorado River Basin. 

CRSS: Colorado River Simulation 

System—is one of two river system 

models developed and maintained by 

the Bureau of Reclamation to support 

operational decision-making and 

planning for the Colorado River Basin. 

Customer: Firm electric service 

customer(s) contractually receiving 

SLCA/IP power and energy. 

Customer Rate Brochure: A document 

prepared for public distribution 

explaining the rationale and background 

for the information contained in the 

Proposed FRN and in this rate order. 

CY: Calendar Year. When used in the 

CRC it is the 12-month period (January 

through December) the CRC is in effect. 

DSA: Deliverable Sales Amount— 

marketable generation level, above 

which WAPA will forgo Purchased 

Power. 

Energy Rate: The rate which sets forth 

the charge for energy. It is expressed in 

mills/kWh and applied to each kWh 

delivered to each Customer. 

Firm: A type of product or service 

available at the time requested by the 

Customer. 

FRN: Federal Register Notice—a 

document published in the Federal 

Register. 

FY: WAPA’s fiscal year, October 1 to 

September 30. 

GWh: Gigawatthour—the electrical 

unit of energy that equals 1 billion 

watthours or 1 million kWh. 

Integrated Projects: The resources and 

revenue requirements of the Collbran, 

Dolores, Rio Grande, and Seedskadee 

projects blended with the CRSP to 

create the SLCA/IP resources and rate. 

kW: Kilowatt—the electrical unit of 

capacity that equals 1,000 watts. 

kWh: Kilowatt-hour—the electrical 

unit of energy that equals 1,000 watts in 

1 hour. 

kWmonth: Kilowatt-month—the 

electrical unit of the monthly amount of 

capacity. 

Load: The amount of electric power or 

energy delivered or required at any 

specified point(s) on a system. 

Load Factor: The percentage of actual 

kWh delivered on a system in a 

designated period of time, as opposed to 

the total possible kWh that could be 

delivered on a system in a designated 

period time. 

Mill: A monetary denomination of the 

United States that equals one tenth of a 

cent or one thousandth of a dollar. 

MAF: Million Acre-Feet—the number 

of gallons of water required to cover 1 

million acres, 1 foot in depth. 

Mills/kWh: Mills per kilowatthour— 

the unit of charge for energy. 

MOA: Memorandum of Agreement 

concerning the Basin Fund for Upper 

Division States to share their 


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apportionment with each other through 

FY 2037. This agreement reduces the 

impact on the CRSP Firm Power rate by 

eliminating the collection of power 

revenue beyond the amount needed to 

repay the costs for participating 

irrigation projects. 

MW: Megawatt—the electrical unit of 

capacity that equals 1 million watts or 

1,000 kilowatts. 

MWh: One million watt-hours of 

electric energy. A unit of electrical 

energy which equals 1 megawatt of 

power used for 1 hour. 

NEPA: National Environmental Policy 

Act of 1969, as amended. 

New Rate Trigger: Under a New Rate 

Trigger, CRSP–MC would reassess an 

implemented CRC when the new rate 

goes into effect to determine if the 

implemented CRC should be superseded 

or terminated. 

OATT: Open Access Transmission 

Tariff, including all schedules or 

attachments thereto, as amended from 

time to time and approved by FERC. 

O&M: Operation and maintenance 

expenses. 

Order RA 6120.2: DOE Order 

outlining Power Marketing 

Administration financial reporting and 

rate-making procedures. 

Participating Projects: The Dolores 

and Seedskadee projects participating 

with CRSP according to the CRSP Act 

1956. 

Pinch Point: The year in the PRS that 

requires the greatest amount of revenue. 

Power: Capacity and energy. 

Project Use: Power used to operate 

SLCA/IP and CRSP facilities under 

Reclamation Law. 

Proposed Rate: A rate that has been 

recommended by WAPA. 

Provisional Rate: A rate which has 

been confirmed, approved, and placed 

into effect on an interim basis by the 

Secretary or his/her designee. 

Power Repayment Study (PRS): 

Defined in DOE Order RA 6120.2 as a 

study portraying the annual repayment 

of power production and transmission 

costs of a power system through the 

application of revenues over the 

repayment period of the power system. 

The study shows, among other items, 

estimated revenues and expenses, year 

by year, over the remainder of the power 

system’s repayment period (based upon 

conditions prevailing over the cost 

evaluation period), the estimated 

amount of Federal investment amortized 

during each year, and the total 

estimated amount of Federal investment 

remaining to be amortized. 

Ratesetting PRS: The SLIP PRS used 

for the rate adjustment proposal. 

Reclamation Law: A series of Federal 

laws. Viewed as a whole, these laws 

create the originating framework under 

which WAPA markets power. 

Revenue Requirement: The revenue 

required by the PRS to recover O&M 

expenses, purchased power and 

transmission service expenses, interest, 

deferred expenses, and repayment of 

Federal investments, or other assigned 

costs. 

SHP: Sustainable Hydro Power (longterm SLCA/IP hydro capacity with 

energy). 

SLIP PRS: CRSP PRS that includes the 

Collbran, Dolores, Rio Grande, and 

Seedskadee revenue requirements. 

Supporting Documentation: A book of 

data that supports this rate action and 

associated rates brochure. 

Work Plan: An estimate of costs that 

are expected to become the 

Congressional Budget for WAPA and 

Reclamation. Also known as a Work 

Program. 

WRF: Western Replacement 

Firming—WRF is optional purchased 

power to firm to customers’ Sustainable 

Hydropower (SHP) allocation levels, the 

cost of which is passed through to firm 

power customers under a separate 

charge for those customers electing 

WRF. 

Effective Date 

The Provisional Rate Schedules SLIP– 

F13, SP–NW6, SP–PTP10, SP–NFT9, 

SP–UU3, SP–EI6, SP–SSR6, SP–SS2, 

and SP–NFJDT will take effect on the 

first day of the first full billing period 

beginning on or after January 1, 2024, 

and will remain in effect through 

December 31, 2028, pending approval 

by FERC on a final basis or until 

superseded. 

Public Notice and Comment 

CRSP MC followed the Procedures for 

Public Participation in Power and 

Transmission Rate Adjustments and 

Extensions, 10 CFR part 903, in 

developing these rates. CRSP MC took 

the following steps to involve interested 

parties in the rate process: 

1. On June 22, 2023, a Federal 

Register notice (88 FR 40813) (Proposal 

FRN) announced the proposed rates and 

launched a 71-day public consultation 

and comment period, set to end on 

September 1, 2023. The original public 

consultation and comment period was 

shorter than 90 days, in accordance with 

10 CFR 903.14(a). The CRSP MC 

shortened the comment period to less 

than 90 days for good cause. There was 

a delay in processing the Proposal FRN 

resulting from the unexpected loss of 

key rates personnel. Decreasing the 

comment period timeframe was deemed 

necessary to implement the new rate 

effective January 1, 2024. 

2. On June 22, 2023, CRSP MC 

notified all Customers and interested 

parties of the proposed rates and 

provided a copy of the Proposal FRN 

and the link to the WAPA–206 rate 

action site at: www.wapa.gov/aboutwapa/regions/crsp-2/rates/rate-order206 (website). 

3. On July 19, 2023, CRSP MC held a 

Public Information Forum (PIF) in Salt 

Lake City, Utah. The PIF was held both 

in-house, as well as virtually. CRSP 

MC’s representatives explained the 

proposed rates, answered questions, and 

gave notice that additional information 

was made available in the Customer 

Rate Brochure. 

4. On August 15, 2023, CRSP MC held 

a virtual public comment forum to 

provide an opportunity for customers 

and other interested parties to comment 

for the record. 

5. During the consultation and 

comment period, which ended on 

October 3, 2023, CRSP MC received four 

oral comments (two at the August 15, 

2023, and two at the September 19, 

2023, public comment forums) and eight 

written sets of comments. CRSP MC 

posted an updated Rate Brochure and 

Supporting Documents to the website 

on September 19, 2023. The other 

comments and CRSP MC’s responses are 

addressed below. 

6. On August 18, 2023, CRSP MC held 

a webinar on purchased power data 

sources and calculations. 

7. On August 28, 2023, CRSP MC 

notified customers and interested 

parties via email, extending the 

consultation and comment period from 

September 1, 2023, to October 3, 2023. 

The comments received during the 

extended comment period and CRSP 

MC’s responses are addressed below. 

CRSP MC posted the comments to the 

website on October 12, 2023. All 

comments have been considered in the 

preparation of this Rate Order. 

Oral comments were received from 

the following organization: 

Colorado River Energy Distributors 

Association (CREDA) 

Arizona Electric Power Cooperative 

(AEPCO) 

Written comments were received on 

behalf of the following organizations 

during the original and extended 

comment periods: 

Arizona Electric Power Cooperative 

(AEPCO) 

Colorado River Energy Distributors 

Association (CREDA) 

Electrical District No. 4 of Pinal County 

(ED4) 

Electrical District No. 7 of Maricopa 

County (ED7) 

Irrigation & Electrical Districts 

Association of Arizona (IEDA) 


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Maricopa Water District (MWD) 

Navajo Tribal Utility Authority (NTUA) 

Wyoming Municipal Power Agency 

(WMPA) 

Power Repayment Study—Firm Power 

Service Rate Discussion 

CRSP MC prepares PRSs each FY to 

determine if revenues will be sufficient 

to repay, within the required time, all 

costs assigned to the SLCA/IP. 

Repayment criteria are based on 

applicable laws and legislation as well 

as policies including DOE Order RA 

6120.2. Under the existing rate 

methodology, rates for firm power 

service are designed to recover an 

annual revenue requirement that 

includes power investment repayment, 

aid to irrigation repayment, interest, 

purchase power, O&M, and other 

expenses within the allowable period. 

To meet the Cost Recovery Criteria 

outlined in DOE Order RA 6120.2, the 

CRSP MC developed a rate adjustment 

to demonstrate sufficient revenues will 

be collected under the Provisional Rates 

to meet future obligations. The revenue 

requirement for SLCA/IP firm power 

service decreased slightly, while the 

energy and capacity rates are set to 

remain the same, as indicated in Table 

1: 

TABLE 1—COMPARISON OF REVENUE REQUIREMENTS AND RATES

Firm power service 

Existing 

requirements 

under SLIP–F12 

(December 1, 

2021) 

Provisional 

requirements 

under SLIP–F13 

(January 1, 2024) 

Percent 

change 

Revenue Requirement (million $) ................................................................................ $181,197 $180,239 ¥0.5 

Energy Rate (mills/kWh) .............................................................................................. 12.36 12.36 0.0 

Capacity Rate ($/kWmonth) ........................................................................................ 5.25 5.25 0.0 

Statement of Revenue and Related 

Expenses 

Table 2 provides a comparison of the 

average annual expense data for the 

SLCA/IP firm power service revenue 

requirement through the rate-setting 

period. 

TABLE 2—ANNUAL REVENUE REQUIREMENTS AND FIRM POWER RATES COMPARISON TABLE

Existing rate, 

SLIP–F12 

($1,000) 

Provisional 

rate, 

SLIP–F13 

($1,000) 

Difference 

($1,000) 

Rate Setting Period ..................................................................................................................... 2022–2045 2024–2045 ........................

Revenue Distribution: 

Expenses: 

O&M ............................................................................................................................................. $103,095 $111,548 $8,453 

Purchase Power .......................................................................................................................... $833 $1,136 $303 

Transmission ................................................................................................................................ $8,984 $7,000 ($1,984) 

Integrated Projects requirements ................................................................................................ $7,043 $7,501 $458 

Interest ......................................................................................................................................... $6,207 $11,152 $4,945 

Other ............................................................................................................................................ $13,547 $13,508 ($39) 

Total Expenses ..................................................................................................................... $139,709 $151,845 $12,136 

Principal Payments: 

Capitalized Expenses (deficits) ................................................................................................... $838 $0 ($838) 

Replacements .............................................................................................................................. $29,581 $13,702 ($15,879) 

Original Project and Additions ..................................................................................................... $1,846 $936 ($910) 

Irrigation ....................................................................................................................................... $9,223 $13,756 $4,533 

Total Principal Payments ...................................................................................................... $41,488 $28,394 ($13,094) 

Annual Revenue Requirement .................................................................................................... $181,197 $180,239 ($958) 

Composite Rate ........................................................................................................................... 30.51 31.38 2.85% 

Energy Rate (mills/kWh) .............................................................................................................. 12.36 12.36 0.00% 

Capacity Rate ($/kWmonth) ........................................................................................................ 5.25 5.25 0.00% 

Any purchased power expense 

required to supplement hydropower 

deliveries up to contractual levels will 

be passed through to Customers under 

a separate charge, WRF, which would be 

in addition to the rate for hydropower 

deliveries. Any Customer not receiving 

WRF will not be charged the purchased 

power charge and would receive its 

proportionate amount of the DSA 

capacity and energy from WAPA each 

month. 

SLCA/IP Firm Power Rate 

The revenue requirement for Rate 

Schedule SLIP–F13 is based on FY 2022 

financial data, WAPA and 

Reclamation’s FY 2025 Work Plans, and 

Reclamation’s August 2023 24-Month 

Study (24-month Study) and the April 

2023 CRSS traces. 

For the first two years of the effective 

rate period, FY 2024 and FY 2025, CRSP 

MC is basing sales in the rate on 

forecasted generation from 

Reclamation’s August 2023 24-month 

Study and is basing sales for the last 


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three years of the effective rate period, 

FY 2026 through FY 2028, on forecasted 

generation from Reclamation’s April 

2023 CRSS Traces. Additionally, Rate 

Schedule SLIP–F13 includes actions 

CRSP MC will take should Lake 

Powell’s water level drop below the 

level at which power can be generated. 

CRSP MC will not automatically 

purchase firming power to SHP levels. 

For those Customers who elect, CRSP 

MC will purchase WRF power as a passthrough cost, at market rates, up to SHP 

levels. CRSP MC will purchase power to 

firm to the forecasted generation level, 

referred to as the DSA. CRSP MC will 

continue to use the DSA methodology 

established in Rate Order No. WAPA– 

199 to address drought conditions in the 

southwestern United States and volatile 

purchased power costs. The DSA will be 

updated quarterly as shown in Table 3. 

Customers will have at least 14 days to 

affirmatively select WRF for each 

quarter. Quarterly notices provide 

flexibility in responding to changes in 

hydrology and will not impact the rates. 

Customers can elect the full quarter or 

specific months within the quarter. 

TABLE 3—DELIVERABLE SALES AMOUNT QUARTERLY UPDATES TO CUSTOMERS

Quarter 24-Month study Customer notification (estimated) Start date 

Q2 Jan–Mar ............................................. November ................................................ November 20 .......................................... January 1. 

Q3 Apr–Jun .............................................. February .................................................. February 20 ............................................. April 1. 

Q4 Jul–Sep .............................................. May ......................................................... May 20 .................................................... July 1. 

Q1 Oct–Dec ............................................. August ..................................................... August 20 ................................................ October 1. 

Deliverable Sales Amount 

Under the DSA methodology, sales 

are limited to projected generation, and 

CRSP MC will make firming purchases 

up to the forecasted DSA level. FY 2022 

and FY 2023 costs for operational 

expenses necessary to meet DSA have 

been included in the rate. Outyear DSA 

energy projections are based on 

Reclamation’s August 2023 24-month 

study (for FY 2024 and FY 2025) and 

Reclamation’s April 2023 CRMMS study 

through the end of the rate setting 

period (for FY2026, FY2027, and 

FY2028). CRSP MC will continue to 

offer the WRF product. WRF is optional 

purchased power to firm to customers’ 

Sustainable Hydropower (SHP) 

allocation levels, the cost of which is 

passed through to firm power customers 

under a separate charge for those 

customers electing WRF. Both DSA and 

WRF will continue to be updated 

quarterly using the applicable 24-month 

study from Reclamation. WRF will 

continue to be billed as it is requested 

to match cost collection with cost 

occurrence. 

Any customer electing not to receive 

its share of the purchased power costs 

through WRF will not be charged for 

WRF. These customers will receive a 

proportionate amount of capacity and 

energy from CRSP MC each month 

under the DSA, charged at the proposed 

firm power rate, reflecting projected 

hydropower generation levels. 

Cost Recovery Charge 

CRSP MC maintains the ability to 

implement a CRC, if necessary. The CRC 

is a mechanism to adequately recover 

and maintain a sufficient balance in the 

Basin Fund in the event projected 

expenses significantly exceed projected 

revenue estimates. The Basin Fund is a 

revolving fund and operates without 

annual appropriations. The CRC is an 

additional surcharge on all SHP energy 

deliveries, which are long-term energy 

sales provided under WAPA’s SLCA/IP 

firm electric service contracts. The CRC 

may be implemented when, among 

other things, the Basin Fund’s cash 

balance is at risk due to low 

hydropower generation, high prices for 

firming power, or emergency capitalized 

investment funding. The CRC is based 

only on Basin Fund cash analysis and 

is independent of the SLCA/IP PRS 

calculations. 

CRSP Transmission Services 

In accordance with WAPA’s OATT, 

CRSP MC offers Network Integration 

Transmission Service, Firm, Non-Firm 

Point-to-Point, and Joint Dispatch 

Transmission Services (JDTS). These 

services include the transmission of 

energy to points of delivery on the CRSP 

interconnected high-voltage system, 

which is comprised of transmission 

lines, substations, and related facilities. 

The transmission rates include the cost 

for Scheduling, System Control, and 

Dispatch Service. The CRSP MC is 

proposing no change to the formula 

rates associated with the CRSP 

Transmission Services; only to make the 

effective dates align with the SLCA/IP 

firm power rate time period. The 

Provisional Rates are as described in the 

respective Rate Schedules and apply to 

transmission-only sales. 

Network Integration Transmission 

Service, Firm, and Non-Firm Point-toPoint Transmission Services, Formula 

Rates SP–NW6 (Network), SP–PTP10 

(Firm) and SP–NFT9 (Non-Firm) 

The Provisional Rates are as described 

in the Rate Schedules and apply to 

transmission-only sales. The cost of 

transmission service for WAPA’s SLCA/ 

IP long-term, firm electric service will 

continue to be included in the SLCA/IP 

firm power rate. 

Joint Dispatch Transmission Service, 

Formula Rate SP–NFJDT 

Rate Schedule SP–NFJDT is used 

when CRCM is participating in the 

WEIS market. JDTS customers shall 

compensate the CRSP Transmission 

Service Provider for JDTS 

commensurate with the receipt or 

delivery of energy dispatched for the 

JDTS Customer pursuant to the WEIS 

Tariff under the formula rate described 

herein. 

Unreserved Use Penalties, Formula Rate 

SP–UU3 

Unreserved Use occurs when an 

eligible customer uses transmission 

service that it has not reserved, or a 

transmission customer uses 

transmission service in excess of its 

reserved capacity. Unreserved Use may 

also include a customer’s failure to 

curtail transmission when requested. 

The Transmission Customer shall 

compensate the CRSP Transmission 

Service Provider each month for any 

unreserved use of the transmission 

system under the applicable 

transmission service rates as outlined 

herein. 

Ancillary Services 

Energy Imbalance (EI) and Generator 

Imbalance (GI) Services, Formula Rate 

SP–EI6 

No changes to the rate schedule for 

energy imbalance and generator 

imbalance under proposed Rate 

Schedule SP–EI6. EI/GI Services are 

provided through the Western Area 

Colorado Missouri (WACM) Balancing 

Authority under Rate Schedules L–AS4 

and L–AS9, or as superseded. 


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Spinning and Supplemental Reserves 

Services, Formula Rate SP–SSR6 

No changes to the rate schedule for 

spinning and supplemental reserves 

services under proposed Rate Schedule 

SP–SSR6. The transmission customer 

serving loads within the transmission 

provider’s balancing authority must 

acquire Spinning and Supplemental 

Reserve services from CRSP, from a 

third party, or by self-supply. 

Sale of Surplus Products, Formula Rate 

SP–SS2 

No changes to the rate schedule for 

sale of surplus products under proposed 

Rate Schedule SP–SS2. The charge for 

each product will be determined at the 

time of the sale based on market rates, 

plus administrative costs. The customer 

will be responsible for acquiring 

transmission service necessary to 

deliver the product(s), for which a 

separate charge may be incurred. 

Comments 

WAPA received 41 separate oral and/ 

or written comments during the public 

consultation and comment period. The 

comments expressed have been 

paraphrased and/or combined, where 

appropriate, without compromising the 

meaning of the comments. 

Comments on Firm Power Rates 

A. Comment: Commentors 

recommended CRSP MC implement a 2- 

year Firm Power rate instead of the 

proposed 5-year rate, due to concerns 

with instability of hydrological 

conditions and potential developing 

market situations. 

Response: CRSP MC is implementing 

a 5-year rate to help with long term rate 

stability and based on established 

business processes will continue to 

annually reassess rate adequacy versus 

changes to budgets, hydrological 

conditions, and any other rate affecting 

factors. If CRSP MC identifies factors 

prompting an update to the rate, CRSP 

MC will initiate a public process to 

implement a new rate. 

B. Comment: A commentor expressed 

support for CRSP MC’s goal to maintain 

the rate the same as currently in effect 

per WAPA–199. 

Response: CRSP MC appreciates the 

feedback. 

Comment on Transmission 

A. Comment: A commentor asked that 

if customers are only getting DSA levels, 

with little to no firming, why does CRSP 

MC forecast transmission demand used 

to develop the CRSP transmission rate 

in excess of reasonably anticipated 

levels of Sustainable Hydroelectric 

Power (‘‘SHP’’), DSA, and the CROD, 

over portions of the forecast period thus 

restricting the transmission capacity 

from being offered to others to enable 

renewable generators to replace aging 

coal plants; plus, this over statement of 

reservations increases the costs to the 

SLCA/IP power rates. 

Response: The CRSP MC has, for well 

over a decade, held the current amount 

of point-to-point transmission capacity. 

CRSP MC reasonably projects this 

amount of capacity will continue to be 

needed within the rate-making window. 

Although DSA levels reflect projected 

generation, they remain uncertain due 

to changes in water releases. Firming 

purchases are often necessary even in 

months where hydropower generation is 

higher than normal; firming purchases 

and excess energy sales are made in 

shoulder hours as hydrologic operations 

cannot respond immediately to 

customer schedules. CRSP MC is unique 

in its use of point-to-point transmission, 

as opposed to network transmission 

service, but has found that point-topoint reservations best ensure it can 

successfully operate during periods 

when water releases and energy 

generation are higher than normal, such 

what occurred in the summer of 2003, 

as well as respond to outage conditions 

allowing rerouting of energy schedules 

without disruption, as well as to meet 

requirements of power replacement 

programs. 

Comments on Purchased Power 

A. Comment: A commentor stated that 

WAPA–199’s primary objective was to 

maintain a sufficient balance in the 

Basin Fund, while obligating the 

responsibility of replacement power to 

the customers. With almost two years of 

operating experience under that 

paradigm, they recommended that CRSP 

MC continue to maintain the same rate 

by including $0 in the WAPA–206 

purchased power line item, consistent 

with WAPA–199. They also noted that 

WAPA–206 continues the customers’ 

responsibility of making replacement 

power purchases, which reduces the 

Basin Fund’s obligations. Given the 

positive hydrology the Colorado River 

system experienced this spring, and the 

results of the August 2023 24-month 

study projections, and in support of a 

two-year rate, the Basin Fund should be 

able to support any firming purchases 

required for operational purposes. 

Response: Due to timing-based 

operational needs, CRSP MC continues 

to experience purchased power 

expenses to meet customer energy 

needs, especially in shoulder hours of 

the scheduling day. CRSP MC’s rate 

design takes into account those timing 

based operational purchased power 

expenses. 

Comments on Other 

A. Comment: A commentor 

recommended that CRSP MC and 

Reclamation continue to evaluate the 

cost assignment based on the concept of 

‘‘beneficiary pays’’. 

Response: CRSP MC appreciates the 

comment. CRSP MC agrees with the 

concept of beneficiary pays and 

continues to work with Reclamation to 

update cost-allocations as appropriate. 

B. Comment: Commentor requested 

that $1.624 million be removed from the 

‘‘Other Expense’’ category based on 

pending legislative changes supported 

by the seven Colorado River Basin 

States, for the Colorado River Salinity 

Control Program, which changes center 

around non-reimbursable and reducing 

the Basin Fund’s obligations. 

Response: At the time Reclamation 

provides a final decision regarding the 

Salinity obligation, those assumptions, 

along with all annual results of 

operations, will be vetted through the 

SLIP PRS for annual rate impact 

assessment. If within those annual 

assessments we find there is a need to 

amend or adjust the existing rate, we 

will then engage customers and the 

public to inform them of current 

recommendations. As of August 2023, 

Reclamation shared that the proposed 

language to the Salinity Control Act 

23639 is still undergoing discussion. 

C. Comment: A commenter 

appreciated CRSP MC’s inclusion of a 

rate brochure statement that the 

proposed rate does not ‘‘imply any 

interpretation of or waiver of any of the 

terms and conditions of the Firm 

Electric Service contracts.’’ While the 

rate may reflect an operational paradigm 

which hopefully will improve in 

coming years, the sanctity of the FES 

contracts has not changed with the rate 

structures originally proposed in 

WAPA–199 and will continue with 

WAPA–206. 

Response: CRSP MC appreciates the 

comment and support. 

Comments on CRSP’s Proposal To 

Participate in the Southwest Power 

Pool Regional Transmission 

Organization 

A. Comment: A commenter stated that 

WAPA has never provided any 

transparent, documented analysis of the 

impact of [WAPA’s] decision to pursue 

SPP membership on CRSP contractors’ 

costs. This void in the administrative 

record makes it difficult to see how 

WAPA expects to make the showing 

required by Section 3 of Delegation 

Order No. 204–108, 58 FR 59716, 59717 


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7The determination was done in compliance with 

NEPA (42 U.S.C. 4321–4347); the Council on 

Environmental Quality Regulations for 

implementing NEPA (40 CFR parts 1500–1508); and 

DOE NEPA Implementing Procedures and 

Guidelines (10 CFR part 1021). 

(1993) for review and confirmation of 

the WAPA–206 rates: that ‘‘the rates are 

the lowest possible to customers 

consistent with sound business 

principles.’’ 

Response: These concerns have been 

addressed in a separate public process 

specific to this subject. On April 28, 

2023, WAPA published an FRN (88 FR 

26298) with a ‘‘Recommendation for the 

Western Area Power Administration’s 

Rocky Mountain Region and Colorado 

River Storage Project Management 

Center to Pursue Final Negotiations 

Regarding Membership in the 

Southwest Power Pool Regional 

Transmission Organization, and for the 

Upper Great Plains Region To Expand 

Its Participation.’’ WAPA engaged in 

outreach to customers and other 

interested stakeholders via a public 

information meeting followed by a 

question-and-answer session on May 11, 

2023. WAPA then held a follow up 

public question-and-answer session on 

May 25, 2023. WAPA reopened the 

comment period and held an additional 

narrowly focused information webinar 

and question-and-answer session on 

June 27, 2023. Over the course of the 75- 

day public comment period, WAPA 

received 69 written comment letters. 

The written comments and a summary 

of WAPA’s responses are available on 

WAPA’s website: www.wapa.gov/aboutwapa/key-topics-2/southwest-powerpool-membership. 

B. Comment: A commenter stated it 

has a good working relationship with 

WAPA that allows the customer to 

import and export power necessary for 

economic growth but is concerned that 

WAPA’s expanded participation in SPP 

could jeopardize the customer’s ability 

to continue to do so economically. The 

customer respectfully requests that any 

final agreement on WAPA’s 

membership and expanded 

participation in SPP include provisions 

to protect the customer’s existing 

contract rights. 

Response: CRSP MC appreciates the 

comment. As responded to in a previous 

comment, WAPA published a Federal 

Register notice (FRN) with a 

‘‘Recommendation for the Western Area 

Power Administration’s Rocky 

Mountain Region and Colorado River 

Storage Project Management Center to 

Pursue Final Negotiations Regarding 

Membership in the Southwest Power 

Pool Regional Transmission 

Organization, and for the Upper Great 

Plains Region To Expand Its 

Participation’’ on April 28, 2023. 

Information about this process and 

proposal, as well as responses to 

customer comments and questions, and 

decision documents are available on 

WAPA’s website: www.wapa.gov/aboutwapa/key-topics-2/southwest-powerpool-membership. 

Certification of Rates 

I have certified that the Provisional 

Rates for SLCA/IP firm power and sales 

of surplus products and the CRSP 

transmission and ancillary services 

under Rate Schedules SLIP–F13, SP– 

NW6, SP–PTP10, SP–NFT9, SP–UU3, 

SP–EI6, SP–SSR6, SP–SS2, and SP– 

NFJDT are the lowest possible rates, 

consistent with sound business 

principles. The Provisional Rates were 

developed following administrative 

policies and applicable laws. 

Availability of Information 

Information used by CRSP MC to 

develop the Provisional Rates is 

available for inspection and copying at 

the Colorado River Storage Project 

Management Center, Western Area 

Power Administration, 1800 South Rio 

Grande Avenue, Montrose, CO 81401. 

Many of these documents are also 

available on WAPA’s website: 

www.wapa.gov/about-wapa/regions/ 

crsp-2/rates. 

Ratemaking Procedure Requirements 

Environmental Compliance 

WAPA has determined that this 

action fits within the following 

categorical exclusion listed in appendix 

B to subpart D of 10 CFR 1021.410: B4.3 

(Electric power marketing rate changes). 

Categorically excluded projects and 

activities do not require preparation of 

either an environmental impact 

statement or an environmental 

assessment.7 A copy of the categorical 

exclusion determination is available on 

WAPA’s website: www.wapa.gov/aboutwapa/regions/crsp-2/about-crsp/ 

environment-3. 

Determination Under Executive Order 

12866 

WAPA has an exemption from 

centralized regulatory review under 

Executive Order 12866; accordingly, no 

clearance of this notice by the Office of 

Management and Budget is required. 

Submission to the Federal Energy 

Regulatory Commission 

The Provisional Rates herein 

confirmed, approved, and placed into 

effect on an interim basis, together with 

supporting documents, will be 

submitted to FERC for confirmation and 

final approval. 

Order 

In view of the above, and under the 

authority delegated to me, I hereby 

confirm, approve, and place into effect, 

on an interim basis, Rate Order No. 

WAPA–206. The rates will remain in 

effect on an interim basis until: (1) FERC 

confirms and approves them on a final 

basis; (2) subsequent rates are confirmed 

and approved; or (3) such rates are 

superseded. 

Signing Authority 

This document of the Department of 

Energy was signed on November 20, 

2023, by Tracey A. LeBeau, 

Administrator, Western Area Power 

Administration, pursuant to delegated 

authority from the Secretary of Energy. 

That document, with the original 

signature and date, is maintained by 

DOE. For administrative purposes only, 

and in compliance with requirements of 

the Office of the Federal Register, the 

undersigned DOE Federal Register 

Liaison Officer has been authorized to 

sign and submit the document in 

electronic format for publication, as an 

official document of the Department of 

Energy. This administrative process in 

no way alters the legal effect of this 

document upon publication in the 

Federal Register. 

Signed in Washington, DC, on November 

21, 2023. 

Treena V. Garrett, 

Federal Register Liaison Officer, U.S. 

Department of Energy. 

Rate Schedule SLIP–F13 

(Supersedes Rate Schedule SLIP–F12) 

UNITED STATES DEPARTMENT OF 

ENERGY WESTERN AREA POWER 

ADMINISTRATION 

Colorado River Storage Project 

Management Center Salt Lake City 

Area Integrated Projects 

Schedule of Rates for Firm Power 

Service (Approved Under Rate Order 

No. WAPA–206) 

Effective: 

The first day of the first full billing 

period beginning on or after January 1, 

2024, and extending through December 

31, 2028, or until superseded by another 

rate schedule, whichever occurs earlier. 

Available: 

In the area served by the Salt Lake 

City Area Integrated Projects. 

Applicable: 

To the wholesale power Customer for 

firm power service supplied through 

one meter at one point of delivery or as 

otherwise established by contract. 

Character: 


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Alternating current, 60 hertz, threephase, delivered and metered at the 

voltages and points established by 

contract. 

Monthly Rate: 

DEMAND CHARGE: $5.25 per 

kilowatt of billing demand. 

ENERGY CHARGE: $12.36 mills per 

kilowatthour of use of Deliverable Sales 

Amount (DSA) energy. 

Modification of Purchase Power: 

WAPA has included an amount of 

expense to represent the inefficiencies 

of market transactions and incidental 

firming costs associated with DSA 

energy scheduling. For more significant 

firming expenses, WAPA will provide a 

pass-through cost option to purchase 

firming power from the DSA level up to 

Sustainable Hydropower (SHP) levels 

for requesting Customers. 

Western Replacement Firming (WRF): 

WRF applies to pass-through 

purchased power costs for energy 

provided between the DSA level and 

SHP energy allocation. WRF is an 

optional product. Customers must elect 

quarterly, and may elect specific months 

within the quarter, to receive WRF. The 

charge for this purchased power will be 

determined at the time of the purchase 

based on market rates. There are no 

losses or an administrative fee charged 

to WRF. A schedule for the quarterly 

updates is in the rate brochure on the 

rate action website: www.wapa.gov/ 

about-wapa/regions/crsp-2/rates/rateorder-206. 

Billing Demand: 

The billing demand will be the greater 

of: 

1. The highest 30-minute integrated 

demand measured during the month up 

to, but not more than, the delivery 

obligation under the power sales 

contract, or, 

2. The Contract Rate of Delivery. 

Billing Energy: 

The billing energy will be the energy 

measured during the month up to, but 

not more than, the delivery obligation 

under the power sales contract. 

Adjustment for Transformer Losses: 

If delivery is made at transmission 

voltage but metered on the low-voltage 

side of the substation, the meter 

readings will be increased to 

compensate for transformer losses as 

provided in the contract. 

Adjustment for Power Factor: 

The Customer will be required to 

maintain a power factor at all points of 

measurement between 95 percent 

lagging and 95 percent leading. 

Adjustment for Western Replacement 

Power (WRP): 

Pursuant to the Customer’s Firm 

Electric Service Contract, as amended, 

WAPA will bill the Customer for its 

proportionate share of the costs of WRP 

within a given time. WAPA will include 

in the monthly power bill the cost of the 

WRP, and the incremental 

administrative costs associated with 

WRP. 

Adjustment for Customer 

Displacement Power (CDP) 

Administrative Charges: 

WAPA will include in the Customer’s 

regular monthly power bill the 

incremental administrative costs 

associated with CDP. 

Adjustment for Minimum Power Pool: 

If Lake Powell drops below 

‘‘minimum power pool’’ and power 

cannot be generated, WAPA will 

provide 30 days’ notice to the 

Customers prior to reducing the DSA 

and will work with Customers to 

mitigate impacts and develop 

alternative solutions. 

Cost Recovery Charge (CRC): 

To adequately recover and maintain a 

sufficient balance in the Basin Fund, 

WAPA uses a cost recovery mechanism, 

called a CRC. The CRC is a charge on 

all long-term energy sales provided 

under WAPA’s SLCA/IP firm electric 

service contracts. 

This charge will be, at a minimum, 

recalculated before July 1 of each year, 

and WAPA will provide notification to 

the Customers consistent with the 

procedures in 10 CFR 903. WAPA has 

the discretion to implement the CRC at 

any point throughout the year using the 

criteria in Table 1. The charge, if 

needed, will be placed into effect on the 

first day of the first full billing period 

beginning on or after the first day of the 

month the CRC is implemented. For the 

purposes of the CRC, the 12-month 

period of a CRC will be described as a 

calendar year (CY). The CRC will be 

calculated as follows: 

TABLE 1—CRC TIERS

Tier Criteria, if the Basin Fund Beginning Balance (BFBB) is: Notification 

i ..................................... Greater than $150 million, with an expected decrease to below $75 million ................... Annually (July). 

ii .................................... Less than $150 million but greater than $120 million, with an expected 50 percent decrease in the next CY.

iii .................................... Less than $120 million but greater than $90 million, with an expected 40 percent decrease in the next CY.

iv ................................... Less than $90 million but greater than $60 million, with an expected 25 percent decrease in the next CY.Semi-Annual (July/January). 

v .................................... Less than $60 million but greater than $40 million with an expected decrease to below 

$40 million in the next CY.

Monthly. 

CRC sample calculations, narratives, 

and schedules showing the dates for 

implementing a CRC throughout the 

year are located at the CRC web page at: 

www.wapa.gov/about-wapa/regions/ 

crsp-2/rates/cost-recovery-charge. 

Waiver Level (WL): 

WAPA will establish a WL that 

provides WAPA the ability to reduce 

purchased power expenses by 

scheduling less energy than what is 

contractually required. Therefore, for 

those Customers who voluntarily 

schedule no more energy than their 

proportionate share of the WL, WAPA 

will waive the CRC for that year. After 

the Funds Available have been 

determined, the WL will be set at the 

sum of the energy that can be provided 

through hydro generation and 

purchased with Funds Available. The 

WL will not be less than the forecasted 

Hydro Energy. 

Trigger for Water Release Criteria: 

In the event that Reclamation’s 24- 

month study projects Glen Canyon Dam 

water releases will drop below 8.23 

million acre feet (MAF) in a water year 

(October through September), WAPA 

will recalculate the CRC to include 

those lower estimates of hydropower 

generation. WAPA, as in the yearly 

projection for the CRC, will give the 

Customers a 45-day notice to request a 

waiver of the CRC if they do not want 

to have the CRC charge added to their 

energy bills. This recalculation will 

remain in effect for the remainder of the 

CY. 

If the annual water release volumes 

from Glen Canyon Dam return to 8.23 

MAF or higher during the trigger 

implementation, a new CRC will be 

calculated for the next month, and the 

Customer will be notified. 


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Trigger for New Rate Criteria: 

WAPA would reassess an 

implemented CRC when a new rate goes 

into effect to determine if the 

implemented CRC should be continued, 

superseded, or terminated. 

Prior Year Adjustment for CRC: 

Since the annual determination of the 

CRC is based upon estimates, an annual, 

prior-year adjustment (PYA) will be 

calculated for those who did not elect 

the waiver level. The PYA will be based 

on the 12-month period the CRC was in 

effect. 

The Customers’ PYA will be based on 

their prior 12-months’ energy multiplied 

by the PYA mills/kWh to determine the 

dollar value that will be assessed. The 

Customer will be charged or credited for 

this dollar amount equally in the 

remaining months of the next 12-month 

billing cycle. WAPA will complete this 

calculation within 2 months of the end 

of the CRC. Therefore, if the PYA is 

calculated in June, the charge/credit 

will be spread over the remaining 9 

months of the CY (July through March). 

Adjustment for CRC Waiver: 

Customers can choose not to take the 

full DSA energy supplied as determined 

in the attached formulas for CRC and 

will be billed the Energy and Capacity 

rates listed above, but not the CRC. 

Rate Schedule SP-NW6 

ATTACHMENT H to Tariff 

(Supersedes Rate Schedule SP-NW5) 

UNITED STATES DEPARTMENT OF 

ENERGY 

WESTERN AREA POWER 

ADMINISTRATION 

Colorado River Storage Project 

Management Center Colorado River 

Storage Project 

Network Integration Transmission 

Service (Approved Under Rate Order 

No. WAPA–206) 

Effective: 

Rate Schedule SP-NW6 will be placed 

into effect on an interim basis on the 

first day of the first full billing period 

beginning on or after January 1, 2024, 

and will remain in effect until FERC 

confirms, approves, and places the rate 

schedules into effect on a final basis 

through December 31, 2028, or until the 

rate schedules are superseded. 

Applicable: 

The Transmission Customer will 

compensate the Colorado River Storage 

Project each month for Network 

Integration Transmission Service under 

the applicable Network Integration 

Transmission Service Agreement and 

the formula rate described herein. 

Formula Rate: 

A calculated Annual Transmission 

Revenue Requirement for Network 

Integration Transmission Service will go 

into effect every October 1 based on the 

above formula and updated financial 

and operational data. WAPA will notify 

the transmission customer annually of 

the recalculated annual Revenue 

Requirement on or before September 1. 

Billing: 

Billing determinants for the formula 

rate above will be as specified in the 

service agreement. Billing will occur 

monthly under the formula rate. 

Adjustment for Losses: 

Losses incurred for service under this 

rate schedule will be accounted as 

agreed to by the parties in accordance 

with the service agreement. If losses are 

not fully provided by a transmission 

customer, charges for financial 

compensation may apply. 

Rate Schedule SP-PTP10 

SCHEDULE 7 to Tariff 

(Supersedes Schedule SP-PTP9) 

UNITED STATES DEPARTMENT OF 

ENERGY 

WESTERN AREA POWER 

ADMINISTRATION 

Colorado River Storage Project 

Management Center Colorado River 

Storage Project 

Firm Point-to-Point Transmission 

Service (Approved Under Rate Order 

No. WAPA–206) 

Effective: 

Rate Schedule SP-PTP10 will be 

placed into effect on an interim basis on 

the first day of the first full billing 

period beginning on or after January 1, 

2024, and will remain in effect until 

FERC confirms, approves, and places 

the rate schedules into effect on a final 

basis through December 31, 2028, or 

until the rate schedules are superseded. 

Applicable: 

The Transmission Customer will 

compensate the Colorado River Storage 

Project each month for Reserved 

Capacity under the applicable Firm 

Point-To-Point Transmission Service 

Agreement and the formula rate 

described herein. 

Formula Rate: 

A recalculated rate will go into effect 

every October 1 based on the above 

formula and updated financial and 

operational data. WAPA will notify the 

transmission customer annually of the 

recalculated rate on or before September 

1. Discounts may be offered from time 

to time in accordance with WAPA’s 

Open Access Transmission Tariff. 

Billing: 

The formula rate above applies to the 

maximum amount of capacity reserved 

for periods ranging from 1 hour to 1 

month, payable whether used or not. 

Billing will occur monthly. 


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Adjustment for Losses: 

Losses incurred for service under this 

rate schedule will be accounted for as 

agreed to by the parties in accordance 

with the service agreement. If losses are 

not fully provided by a transmission 

customer, charges for financial 

compensation may apply. 

Rate Schedule SP-NFT9 

SCHEDULE 8 to Tariff 

(Supersedes Schedule SP-NFT8) 

UNITED STATES DEPARTMENT OF 

ENERGY 

WESTERN AREA POWER 

ADMINISTRATION 

Colorado River Storage Project 

Management Center Colorado River 

Storage Project 

Non-Firm Point-to-Point Transmission 

Service (Approved Under Rate Order 

No. WAPA–206) 

Effective: 

Rate Schedule SP-NFT9 will be 

placed into effect on an interim basis on 

the first day of the first full billing 

period beginning on or after January 1, 

2024, and will remain in effect until 

FERC confirms, approves, and places 

the rate schedules into effect on a final 

basis through December 31, 2028, or 

until the rate schedules are superseded. 

Applicable: 

The Transmission Customer will 

compensate the Colorado River Storage 

Project each month for Non-Firm, Pointto-Point Transmission Service under the 

applicable Non-Firm, Point-to-Point 

Transmission Service Agreement and 

the formula rate described herein. 

Formula Rate: 

A recalculated rate will go into effect 

every October 1 based on the above 

formula and updated financial and load 

data. WAPA will notify the transmission 

customer annually of the recalculated 

rate on or before September 1. Discounts 

may be offered from time-to-time in 

accordance with WAPA’s Open Access 

Transmission Tariff. 

Billing: 

The formula rate above applies to the 

maximum amount of capacity reserved 

for periods ranging from 1 hour to 1 

month, payable whether used or not. 

Billing will occur monthly. 

Adjustment for Losses: 

Power and energy losses incurred in 

connection with the transmission and 

delivery of power and energy under this 

rate schedule shall be supplied by the 

customer in accordance with the service 

contract. If losses are not fully provided 

by a transmission customer, charges for 

financial compensation may apply. 

Rate Schedule SP-UU3 

SCHEDULE 10 to Tariff 

(Supersedes Schedule SP-UU2) 

UNITED STATES DEPARTMENT OF 

ENERGY 

WESTERN AREA POWER 

ADMINISTRATION 

Colorado River Storage Project 

Management Center Colorado River 

Storage Project 

Unreserved Use Penalties (Approved 

Under Rate Order No. WAPA–206) 

Effective: 

Rate Schedule SP-UU3 will be placed 

into effect on an interim basis on the 

first day of the first full billing period 

beginning on or after January 1, 2024, 

and will remain in effect until FERC 

confirms, approves, and places the rate 

schedules into effect on a final basis 

through December 31, 2028, or until the 

rate schedules are superseded. 

Applicable: 

The Transmission Customer shall 

compensate the Colorado River Storage 

Project (CRSP) each month for any 

unreserved use of the transmission 

system (Unreserved Use) under the 

applicable transmission service rates as 

outlined herein. Unreserved Use occurs 

when an eligible customer uses 

transmission service that it has not 

reserved or a transmission customer 

uses transmission service in excess of its 

reserved capacity. Unreserved Use may 

also include a customer’s failure to 

curtail transmission when requested. 

Penalty Rate: 

The penalty rate for a Transmission 

Customer that engages in Unreserved 

Use is 200 percent of CRSP’s approved 

transmission service rate for point-topoint (SP-PTP9) transmission service 

assessed as follows: 

(i) The Unreserved Use Penalty for a 

single hour of Unreserved Use is based 

upon the rate for daily firm PTP service. 

(ii) The Unreserved Use Penalty for 

more than one assessment for a given 

duration (e.g., daily) increases to the 

next longest duration (e.g., weekly). 

(iii) The Unreserved Use Penalty for 

multiple instances of Unreserved Use 

(e.g., more than 1 hour) within a day is 

based on the rate for daily firm PTP 

service. The Unreserved Use Penalty 

charge for multiple instances of 

Unreserved Use isolated to 1 calendar 

week would result in a penalty based on 

the rate for weekly firm PTP service. 

The Unreserved Use Penalty charge for 

multiple instances of Unreserved Use 

during more than 1 week in a calendar 

month will be based on the rate for 

monthly firm PTP service. 

A Transmission Customer that 

exceeds its firm reserved capacity at any 

point of receipt or point of delivery or 

an eligible customer that uses 

transmission service at a point of receipt 

or point of delivery that it has not 

reserved is required to pay for all 

ancillary services identified in WAPA’s 

Open Access Transmission Tariff that 

were provided by the CRSP and 

associated with the Unreserved Use. 

The Transmission Customer will pay for 

ancillary services based on the amount 

of transmission service it used and did 

not reserve. 

Rate: 

The rate for Unreserved Use Penalties 

is 200 percent of WAPA’s approved rate 

for firm point-to-point transmission 

service assessed as described above. 

Any change to the rate for Unreserved 

Use Penalties will be listed in a revision 

to this rate schedule issued under 

applicable Federal laws and policies 

and made part of the applicable service 

agreement. 

Rate Schedule SP–EI6 

SCHEDULES 4 & 9 to Tariff 

(Supersedes Rate Schedule SP–EI5) 

UNITED STATES DEPARTMENT OF 

ENERGY WESTERN AREA POWER 

ADMINISTRATION 

Colorado River Storage Project 

Management Center Colorado River 

Storage Project 

Energy and Generator Imbalance 

Services (Approved Under Rate Order 

No. WAPA–206) 

Effective: 

Rate Schedule SP–EI6 will be placed 

into effect on an interim basis on the 

first day of the first full billing period 

beginning on or after January 1, 2024, 

and will remain in effect until FERC 

confirms, approves, and places the rate 

schedules into effect on a final basis 


khammond on DSKJM1Z7X2PROD with NOTICESEN27NO23.005</GPH>
82890 Federal Register / Vol. 88, No. 226 / Monday, November 27, 2023 / Notices 

through December 31, 2028, or until the 

rate schedules are superseded. 

Applicable: 

To all CRSP Transmission Customers 

receiving this service. 

Formula Rates: 

Provided through the Western Area 

Colorado Missouri (WACM) Balancing 

Authority under Rate Schedules L–AS4 

and L–AS9, or as superseded. 

Rate Schedule SP–SSR6 

SCHEDULES 5 & 6 to Tariff 

(Supersedes Rate Schedule SP–SSR5) 

UNITED STATES DEPARTMENT OF 

ENERGY WESTERN AREA POWER 

ADMINISTRATION 

Colorado River Storage Project 

Management Center Colorado River 

Storage Project 

Operating Reserves—Spinning and 

Supplemental Reserve Services 

(Approved Under Rate Order No. 

WAPA–206) 

Effective: 

Rate Schedule SP–SSR5 will be 

placed into effect on an interim basis on 

the first day of the first full billing 

period beginning on or after January 1, 

2024, and will remain in effect until 

FERC confirms, approves, and places 

the rate schedules into effect on a final 

basis through December 31, 2028, or 

until the rate schedules are superseded. 

Applicable: 

To all CRSP Transmission Customers 

receiving this service. 

Formula Rate: 

The Transmission Customer serving 

loads within the transmission provider’s 

balancing authority must acquire 

Spinning and Supplemental Reserve 

services from CRSP, from a third party, 

or by self-supply. 

Rate Schedule SP–SS2 

(Supersedes Rate Schedule SP–SS1) 

UNITED STATES DEPARTMENT OF 

ENERGY WESTERN AREA POWER 

ADMINISTRATION 

Colorado River Storage Project 

Management Center Colorado River 

Storage Project 

Sale of Surplus Products (Approved 

Under Rate Order No. WAPA–206) 

Effective: 

The first day of the first full billing 

period beginning on or after January 1, 

2024, and extending through December 

31, 2028, or until superseded by another 

rate schedule, whichever occurs earlier. 

Applicable: 

This Rate Schedule applies to the sale 

of the following Salt Lake City Area 

Integrated Projects (SLCA/IP) surplus 

energy and capacity products: energy, 

frequency response, regulation, and 

reserves. If any of the above SLCA/IP 

surplus products are available, SLCA/IP 

can make the product(s) available for 

sale, providing entities enter into 

separate agreement(s) with CRSP 

Marketing which will specify the terms 

of the sale(s). 

Formula Rate: 

The charge for each product will be 

determined at the time of the sale based 

on market rates, plus administrative 

costs. The customer will be responsible 

for acquiring transmission service 

necessary to deliver the product(s), for 

which a separate charge may be 

incurred. 

Rate Schedule SP–NFJDT 

SCHEDULE 8R to OATT Attachment 

(Supersedes Rate Schedule SP–NFJDT 

dated 

October 1, 2021, through September 30, 

2024) 

UNITED STATES DEPARTMENT OF 

ENERGY WESTERN AREA POWER 

ADMINISTRATION 

Colorado River Storage Project 

Management Center Colorado River 

Storage Project 

Joint Dispatch Transmission Service 

(Approved Under Rate Order No. 

WAPA–206) 

Effective: 

The first day of the first full billing 

period beginning on or after January 1, 

2024, and extending through December 

31, 2028, or until superseded by another 

rate schedule, whichever occurs earlier. 

Applicable: 

This rate schedule applies to the 

Colorado River Storage Project (CRSP) 

as the Transmission Service Provider 

(TSP) when the Colorado River Storage 

Project Management Center is 

participating in the Western Energy 

Imbalance Service (WEIS) Market. The 

Joint Dispatch Transmission Service 

(JDTS) Customer shall compensate the 

CRSP TSP for JDTS commensurate with 

the receipt or delivery of energy 

dispatched for the JDTS Customer 

pursuant to the WEIS Tariff under the 

formula rate described herein. 

Formula Rate: 

Hourly delivery: 

On-Peak Hours: the on-peak charge 

$0.00/MWh 

Off-Peak Hours: the off-peak charge 

$0.00/MWh 

[FR Doc. 2023–26049 Filed 11–24–23; 8:45 am] 

BILLING CODE 6450–01–P 

ENVIRONMENTAL PROTECTION 

AGENCY 

[FRL–11565–01–OA] 

Local Government Advisory 

Committee (LGAC) and Small 

Communities Advisory Subcommittee 

(SCAS); Meeting 

AGENCY: Environmental Protection 

Agency (EPA). 

ACTION: Notification of public meeting. 

SUMMARY: Pursuant to the Federal 

Advisory Committee Act (FACA), the 

EPA hereby provides notice of a meeting 

for the Local Government Advisory 

Committee (LGAC) and its Small 

Communities Advisory Subcommittee 

(SCAS) on the date and time described 

below. This meeting will be open to the 

public. For information on public 

attendance and participation, please see 

registration details under 

SUPPLEMENTARY INFORMATION. 

DATES: The LGAC and SCAS will have 

a virtual meeting on December 15th, 

2023, from 1:00 to 2:00 p.m. Eastern 

Standard Time. 

FOR FURTHER INFORMATION CONTACT: 

Paige Lieberman, Designated Federal 

Officer (DFO) of the Local Government 

Advisory Committee, at LGAC@epa.gov 

or 202–564–9957 or Lynzi Barnes, DFO 

of the Small Community Advisory 

Subcommittee, at barnes.edlynzia@

epa.gov or (773) 638–9158. 

Information on Accessibility: For 

information on access or services for 

individuals requiring accessibility 

accommodations, please contact Paige 

Lieberman by email at LGAC@epa.gov. 

To request accommodation, please do so 

five (5) business days prior to the 

meeting, to give EPA as much time as 

possible to process your request. 

SUPPLEMENTARY INFORMATION: 

Content 

The LGAC and SCAS will discuss 

recommendations from the 

environmental justice and equity 

workgroup that involves a cumulative 

impacts framework. Meeting materials 

and recommendations will be posted 

closer to the meeting. 

Registration 

The meeting will be held virtually via 

Microsoft Teams. Members of the public 

who wish to participate should register 

by contacting the Designated Federal 

Officer (DFO) at LGAC@epa.gov by 

December 8th, 2023. Once available, the 

agenda and other supportive meeting 

materials will be available online at 

https://www.epa.gov/ocir/localgovernment-advisory-committee-lgac 


khammond on DSKJM1Z7X2PROD with NOTICES