[Federal Register Volume 88, Number 226 (Monday, November 27, 2023)]
[Notices]
[Pages 82880-82890]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 2023-26049]


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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.

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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Regulatory Commission (FERC) on a final basis or until superseded.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: [email protected]; or Tamala Gheller, Rates 
Manager, Colorado River Storage Project Management Center, Western Area 
Power Administration, 970-240-6545, or email: [email protected].

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-
to-Point 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.
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    \1\ Order Confirming and Approving Rate Schedule on a Final 
Basis, FERC Docket No. EF 22-1-000 (179 FERC ] 62,085 (2022)).
    \2\ Order Confirming and Approving Rate Schedule on a Final 
Basis, FERC Docket No. EF 21-7-000 (178 FERC ] 62,154 (2022)).
    \3\ Order Confirming and Approving Rate Schedules on a Final 
Basis, FERC Docket No. EF 20-7-000 (173 FERC ] 61,230 (2020)).
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    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

[[Page 82881]]

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\
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    \4\ 50 FR 37835 (Sept. 18, 1985) and 84 FR 5347 (Feb. 21, 2019).
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    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\
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    \5\ This 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.
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    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\
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    \6\ 50 FR 37835 (Sept. 18, 1985) and 84 FR 5347 (Feb. 21, 2019).
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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

[[Page 82882]]

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 (long-term 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/about-wapa/regions/crsp-2/rates/rate-order-206 (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)

[[Page 82883]]

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
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                                                               Existing           Provisional
                                                          requirements under  requirements under
                   Firm power service                     SLIP-F12 (December   SLIP-F13 (January  Percent change
                                                               1, 2021)            1, 2024)
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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
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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
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                                                                  Existing rate,    Provisional
                                                                     SLIP-F12     rate, SLIP-F13    Difference
                                                                     ($1,000)        ($1,000)        ($1,000)
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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
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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)
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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

[[Page 82884]]

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 pass-through 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
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                                                                Customer notification
               Quarter                     24-Month study            (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-to-
Point 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.

[[Page 82885]]

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-to-point 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

[[Page 82886]]

(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/about-wapa/key-topics-2/southwest-power-pool-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/about-wapa/key-topics-2/southwest-power-pool-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/about-wapa/regions/crsp-2/about-crsp/environment-3.
---------------------------------------------------------------------------

    \7\ The 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).
---------------------------------------------------------------------------

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:

[[Page 82887]]

    Alternating current, 60 hertz, three-phase, 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/rate-order-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
----------------------------------------------------------------------------------------------------------------
                                             Criteria, if the Basin Fund Beginning
                  Tier                                Balance (BFBB) is:                     Notification
----------------------------------------------------------------------------------------------------------------
i.......................................  Greater than $150 million, with an          Annually (July).
                                           expected decrease to below $75 million.
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  Semi-Annual (July/
                                           million, with an expected 25 percent        January).
                                           decrease in the next CY.
v.......................................  Less than $60 million but greater than $40  Monthly.
                                           million with an expected decrease to
                                           below $40 million in the next CY.
----------------------------------------------------------------------------------------------------------------

    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.

[[Page 82888]]

    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:
    [GRAPHIC] [TIFF OMITTED] TN27NO23.003
    
    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:
    [GRAPHIC] [TIFF OMITTED] TN27NO23.004
    
    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.

[[Page 82889]]

    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, Point-to-Point Transmission 
Service under the applicable Non-Firm, Point-to-Point Transmission 
Service Agreement and the formula rate described herein.
    Formula Rate:
    [GRAPHIC] [TIFF OMITTED] TN27NO23.005
    
    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-to-point (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

[[Page 82890]]

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