Notice2025-12994
Colorado River Storage Project-Rate Order No. WAPA-220
Primary source
Metadata and text below are from the Federal Register, a public-domain U.S. government work. Always verify the official published version before relying on it for any legal matter.
Published
July 11, 2025
Effective
March 31, 2031
Issuing agencies
Energy DepartmentWestern Area Power Administration
Abstract
The formula rates for the Colorado River Storage Project (CRSP) region's transmission and ancillary services for CRSP's costs to be recovered under the Southwest Power Pool's (SPP) Open Access Transmission Tariff (Tariff) should CRSP decide to become a member of SPP, have been confirmed, approved, and placed into effect on an interim basis (Provisional Formula Rate). If CRSP decides to become a member of SPP, these new formula rates under Rate Schedules CRCMT-ATRR (transmission), CRCMT-AS1 (scheduling, system control, and dispatch), and CRCMT-PTP (firm point-to-point) will supersede the existing formula rates for transmission and ancillary services under Rate Schedules SP- NW6, SP-PTP10, SP-NFT9, SP-NFJDT, SP-UU3, SP-EI6, and SP-SSR6, which expire on December 31, 2028.
Full Text
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[Federal Register Volume 90, Number 131 (Friday, July 11, 2025)]
[Notices]
[Pages 30916-30924]
From the Federal Register Online via the Government Publishing Office [<a href="http://www.gpo.gov">www.gpo.gov</a>]
[FR Doc No: 2025-12994]
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DEPARTMENT OF ENERGY
Western Area Power Administration
Colorado River Storage Project--Rate Order No. WAPA-220
AGENCY: Western Area Power Administration, DOE.
ACTION: Notice of rate order concerning transmission and ancillary
services formula rates.
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SUMMARY: The formula rates for the Colorado River Storage Project
(CRSP) region's transmission and ancillary services for CRSP's costs to
be recovered under the Southwest Power Pool's (SPP) Open Access
Transmission Tariff (Tariff) should CRSP decide to become a member of
SPP, have been confirmed, approved, and placed into effect on an
interim basis (Provisional Formula Rate). If CRSP decides to become a
member of SPP, these new formula rates under Rate Schedules CRCMT-ATRR
(transmission), CRCMT-AS1 (scheduling, system control, and dispatch),
and CRCMT-PTP (firm point-to-point) will supersede the existing formula
rates for transmission and ancillary services under Rate Schedules SP-
NW6, SP-PTP10, SP-NFT9, SP-NFJDT, SP-UU3, SP-EI6, and SP-SSR6, which
expire on December 31, 2028.
DATES: The Provisional Formula Rates under Rate Schedules CRCMT-ATRR,
CRCMT-AS1, and CRCMT-PTP are effective on the first day of the first
full billing period beginning on the later of the following events: (1)
when CRSP officially becomes a member of, and transfers functional
control of CRSP transmission facilities to SPP; or (2) the go-live date
of the expansion of the SPP Regional Transmission Organization into the
Western Interconnection (scheduled for April 1, 2026, as of date of
this Rate Order). CRSP will provide notification of the effective date
of the Provisional Formula Rates on its Rates and Open Access Same-Time
Information System websites. These Provisional Formula Rates will
remain in effect through March 31, 2031, pending confirmation and
approval by the Federal Energy Regulatory Commission (FERC) on a final
basis or until superseded. If CRSP does not become a member of SPP,
these rates will be canceled and the existing formula rates will remain
in effect.
FOR FURTHER INFORMATION CONTACT: Rodney G. Bailey, Regional Manager,
Colorado River Storage Project Region,\1\ Western Area Power
Administration, 1800 South Rio Grande Avenue, Montrose, CO 81401-4800,
or Tamala D. Gheller, Rates Manager, Colorado River Storage Project
Region, Western Area Power Administration, (970) 461-7535, or email:
<a href="/cdn-cgi/l/email-protection#3b5c535e57575e497b4c5a4b5a155c544d"><span class="__cf_email__" data-cfemail="b8dfd0ddd4d4ddcaf8cfd9c8d996dfd7ce">[email protected]</span></a>.
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\1\ CRSP's former designation as a ``Management Center'' has
changed to a ``Region,'' effective February 9, 2025.
SUPPLEMENTARY INFORMATION: On June 12, 2024, FERC confirmed and
approved Rate Schedules SP-NW6 (network); SP-PTP10 (firm point-to-
point); SP-NFT9 (non-firm point-to-point); SP-NFJDT \2\ (joint dispatch
transmission); SP-UU3 (unreserved use penalties); SP-EI6 (energy and
generation imbalance); and SP-SSR6 (operating reserves--spinning and
supplemental reserve services) under Rate Order No. WAPA-206 on a final
basis through December 31, 2028.\3\ Western Area Power Administration
(WAPA) published a Federal Register notice (Proposed FRN) on December
30, 2024 (89 FR 106473) proposing new formula rates for CRSP
transmission and ancillary services in order for CRSP to recover its
costs under the SPP Tariff should CRSP decide to become a member of
SPP. The Proposed FRN also initiated a 90-day public consultation and
comment period and set forth the date of the virtual public information
and public comment forums. Consistent with CRSP's current transmission
and ancillary services formula rates, CRSP will continue to use a
formula-based methodology. CRSP will annually update the data used in
the rate formula calculations in accordance with the Formula Rate
Implementation Protocols (Protocols).
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\2\ Rate Schedule SP-NFJDT was not originally listed in Proposed
WAPA-220 as being superseded; however, it was discussed during the
comment and consultation period and is included in the WAPA-220 Rate
Order.
\3\ Order Confirming and Approving Rate Schedules on a Final
Basis, FERC Docket No. EF24-1-000, 187 FERC ] 61,165 (2024).
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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-S3-2024, effective August 30, 2024, the Secretary of Energy also
delegated the authority to confirm, approve, and place such rates into
effect on an interim basis to the 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 Department of Energy
procedures for public participation in rate adjustments set forth in 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 review of CRSP's proposal, Rate Order No. WAPA-220, which
provides formula rates for the Annual Transmission Revenue Requirement
for Transmission Service; Scheduling, System Control, and Dispatch
Service; and Firm Point-to-Point Transmission Service, is hereby
confirmed, approved, and placed into effect on an interim basis. WAPA
will submit Rate Order No. WAPA-220 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
[[Page 30917]]
Storage Project Region, Rate Adjustment for the, Colorado River Storage
Project Transmission and Ancillary Services Formula Rates, Rate Order
No. WAPA-220
Order Confirming, Approving, and Placing the Formula Rates for the
Colorado River Storage Project Into Effect on an Interim Basis
The formula rates in Rate Order No. WAPA-220 are established
following section 302 of the Department of Energy (DOE) Organization
Act (42 U.S.C. 7152).\1\
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\1\ 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 section 5 of the Flood Control Act of 1944 (16 U.S.C.
825s); and other acts that specifically apply to the project
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-S3-2024, effective August 30, 2024, the Secretary of Energy also
delegated the authority to confirm, approve, and place such rates into
effect on an interim basis to the 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. S3DEL-WAPA1-2023 and DOE procedures for public
participation in rate adjustments set forth at 10 CFR part 903.\2\
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\2\ 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:
Attachment H: Attachment H to Southwest Power Pool's (SPP) Open
Access Transmission Tariff (Tariff)--Annual Transmission Revenue
Requirement (ATRR) for Network Integration Transmission Service.
Attachment AI: Attachment AI to SPP's Tariff--Transmission
Definition
Balancing Authority (BA): The responsible entity that integrates
resource plans ahead of time, maintains load-interchange-generation
balance within a designated area, and supports interconnection
frequency in real-time.
Balancing Authority Area (BAA): The collection of generation,
transmission, and loads within the metered boundaries of the Balancing
Authority and contained in one interconnection. The Balancing Authority
maintains load-resource balance within each of these areas. (SPP Tariff
at Part 1, Section 1, B Definitions.)
Customer Rate Brochure: A document prepared for public distribution
explaining the rationale and background for the information contained
in the Proposed Federal Register notice (FRN) and in this rate order.
Firm: A type of product and/or service available at the time
requested by a customer.
FRN: Federal Register notice--a document published in the Federal
Register in order for WAPA to provide information of public interest.
FY: WAPA's Fiscal Year; October 1 to September 30.
NEPA: National Environmental Policy Act of 1969, as amended.
OASIS: Open Access Same-Time Information System--As defined in
WAPA's Tariff, the information system and standards of conduct
contained in Part 37 of the Commission's regulations and all additional
requirements implemented by subsequent Commission orders dealing with
OASIS.
O&M: Operation and maintenance expenses.
Order RA 6120.2: DOE Order outlining Power Marketing Administration
financial reporting and rate-making procedures.
Power: Capacity and energy.
Preference: The provisions of Reclamation Law that require WAPA to
first make Federal Power available to certain entities. For example,
section 9(c) of the Reclamation Project Act of 1939 (43 U.S.C. 485h(c))
states that preference in the sale of Federal Power shall be given to
municipalities and other public corporations or agencies; and also to
cooperatives and other nonprofit organizations financed in whole or in
part by loans made under the Rural Electrification Act of 1936.
Provisional Formula Rates: Formula rate(s) that are confirmed,
approved, and placed into effect on an interim basis by the Secretary
or his/her designee.
Revenue Requirement: The revenue required to recover annual
expenses (such as O&M, administrative and general expenses, interest,
and depreciation).
Schedule 1: Schedule 1 of SPP's Tariff--Scheduling, System Control
and Dispatch Service.
Schedule 9: Schedule 9 of SPP's Tariff--Network Integration
Transmission Service.
Schedule 11: Schedule 11 of SPP's Tariff--Base Plan Zonal Charge
and Region-wide Charge.
Tariff: Open Access Transmission Tariff, including all schedules or
attachments thereto, as amended from time to time and approved by FERC.
Transmission Owner: Each Member of SPP that has executed an SPP
Membership Agreement as a Transmission Owner and therefore has the
obligation to construct, own, operate, and maintain transmission
facilities as directed by the Transmission Provider and: (i) whose
Tariff facilities (in whole or in part) make up the Transmission
System; or (ii) who has accepted a Notification to Construct but does
not yet own transmission facilities under SPP's functional control.
Those Transmission Owners that are not regulated by the Commission
shall not become subject to Commission regulation by virtue of their
status as Transmission Owners under this Tariff; provided, however,
that service over their facilities classified as transmission and
covered by the Tariff shall be subject to Commission regulation. (SPP
Tariff at Part I, Section 1, T Definitions.)
WAPA-CRSP: United States Department of Energy, Western Area Power
Administration (WAPA), Colorado River Storage Project (CRSP). WAPA-CRSP
is the definition for WAPA's Colorado River Storage Project region in
the SPP Tariff and the definition to be used in the rate schedules.
Western Interconnection: A major alternating current power grid in
North America. The Western Interconnection stretches from Western
Canada south to Baja California in Mexico, reaching eastward over the
Rockies to the Great Plains. Western Interconnection is comprised of
the states of Washington, Oregon, California, Idaho, Nevada, Utah,
Arizona, Colorado, Wyoming, portions of Montana, South Dakota,
Nebraska, New Mexico, and Texas in the United States, the Provinces of
British Columbia and Alberta in Canada, and a portion of the
Comisi[oacute]n Federal de Electricidad's system in Baja California in
Mexico. (SPP Tariff at Part I, Section 1, W Definitions.)
[[Page 30918]]
Zone: The geographic area of the facilities of a Transmission Owner
or a specific combination of Transmission Owners as specified in
Schedules 7, 8, and 9. (SPP Tariff at Part I, Section 1, XYZ
Definitions).
Effective Date
The Provisional Formula Rates under Rate Schedules CRCMT-ATRR,
CRCMT-AS1, and CRCMT-PTP, will take effect on the first day of the
first full billing period beginning on the later of the following
events: (1) when the Colorado River Storage Project (CRSP) region
officially becomes a member of, and transfers functional control of
CRSP transmission facilities to, SPP; or (2) the go-live date of the
expansion of the SPP Regional Transmission Organization (RTO) into the
Western Interconnection (scheduled for April 1, 2026, as of date of
this Rate Order). CRSP will provide notification of the effective date
of the Provisional Formula Rates on its Rates and OASIS websites. These
Provisional Formula Rates will remain in effect through March 31, 2031,
pending confirmation and approval by FERC on a final basis or until
superseded. If CRSP does not become a member of SPP, these rates will
be canceled and the existing formula rates will remain in effect. If
canceled, CRSP will inform customers by letter and by posting notice of
such on CRSP's Rates website <a href="http://www.wapa.gov/about-wapa/regions/crsp/rates/2026-rate-adjustment-transmission-and-ancillary-services">www.wapa.gov/about-wapa/regions/crsp/rates/2026-rate-adjustment-transmission-and-ancillary-services</a> and on
CRSP's OASIS website <a href="http://www.oasis.oati.com/CRCM/index.html">www.oasis.oati.com/CRCM/index.html</a>.
Public Notice and Comment
CRSP followed the Procedures for Public Participation in Power and
Transmission Rate Adjustments and Extensions, 10 CFR part 903, in
developing these formula rates. CRSP took the following steps to
involve interested parties in the rate process:
1. On December 30, 2024, a FRN (89 FR 106473) (Proposed FRN)
announced the proposed formula rates and initiated a 90-day public
consultation and comment period.
2. On December 31, 2024, CRSP notified Preference Customers and
interested parties of the proposed rates and provided a copy of the
published Proposed FRN.
3. On February 19, 2025, CRSP held a virtual public information
forum where CRSP's representatives explained the proposed formula
rates, answered questions, and gave notice that more information was
available in the Customer Rate Brochure.
4. On February 19, 2025, CRSP held a virtual public comment forum
to provide an opportunity for customers and other interested parties to
comment for the record.
5. CRSP posted information about this rate process on two public
websites. CRSP's Rates website located at <a href="http://www.wapa.gov/about-wapa/regions/crsp/rates/2026-rate-adjustment-transmission-and-ancillary-services">www.wapa.gov/about-wapa/regions/crsp/rates/2026-rate-adjustment-transmission-and-ancillary-services</a>, and CRSP's OASIS website located at <a href="http://www.oasis.oati.com/CRCM/index.html">www.oasis.oati.com/CRCM/index.html</a>.
6. During the 90-day consultation and comment period, which ended
on March 31, 2025, CRSP received 25 oral comment submissions and six
written comment letters. The comments and CRSP's responses are
addressed in the ``Comments'' section. All comments have been
considered in the preparation of this Rate Order.
Oral comments were received from the following organizations:
Colorado River Energy Distributors Association
Duncan & Allen LLP
Arizona Power Authority
Colorado River Commission of Nevada
Written comments were received from the following organizations:
Arizona Municipal Power Users' Association
Arizona Generation & Transmission Cooperatives
Arizona Power Authority
Colorado River Energy Distributors Association
Duncan & Allen LLP
Irrigation & Electrical Districts Association of Arizona
Grand Canyon State Electric Cooperative Association
Salt River Project
Transmission and Ancillary Rate Discussion
On April 28, 2023, WAPA published a FRN titled ``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'' (88 FR 26298). On June 4, 2024, SPP
submitted revisions to its Tariff, Bylaws, and Membership Agreement to
expand the SPP RTO into the Western Interconnection to FERC.\3\ On
March 20, 2025, FERC accepted, subject to condition and further
compliance filing, SPP's proposed Tariff, Bylaws, and Membership
Agreement revisions. Subject to further approval by WAPA's
Administrator, CRSP plans to become a member of SPP.
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\3\ Southwest Power Pool, Inc., Submission of Revisions to
Tariff, Bylaws, and Membership Agreement to Expand the Regional
Transmission Organization into the Western Interconnections (Part 1
of 2) and (Part 2 of 2), Docket Nos. ER24-2184, ER24-2185 (June 4,
2024).
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CRSP's membership will include CRSP becoming a Transmission Owner
member of SPP. WAPA will transfer functional control of eligible CRSP
transmission facilities to SPP. At such time, for the eligible
facilities, CRSP transmission and ancillary services will no longer be
available under WAPA's Tariff, and the existing transmission and
ancillary services rate schedules, specifically SP-NW6, SP-PTP10, SP-
NFT9, SP-NFJDT, SPUU3, SP-EI6, SP-SSR6, will no longer be applicable.
Additionally, Rocky Mountain region's Rate Schedules L-AS1, L-AS2, and
L-AS3 for ancillary services, which are applicable to CRSP transmission
services, will no longer be applicable.
CRSP transmission service and ancillary services will be provided
under the SPP Tariff by SPP as the transmission service provider.
Accordingly, CRSP has developed new formula rate designs/rate schedules
for specific costs to be recovered under the SPP Tariff. For each
formula rate, the appropriate data will be submitted to SPP in standard
formula rate templates in accordance with Attachment H to SPP's Tariff.
CRSP will identify any portion of its ATRR eligible for recovery under
SPP's Tariff Schedule 9 and Schedule 11 in these formula rate
templates. CRSP's revenue requirements are added to the annual revenue
requirements of other transmission owners in the multi-owner SPP
pricing Zone 103, also identified as the Colorado River Storage Project
Zone (CRSPZ), for transmission service billed by SPP within the CRSPZ.
CRSP's revenue requirements under these rates also impact other costs
for transmission service within the broader SPP footprint.
For each formula rate, CRSP will true up its estimated costs with
actual costs each year. If CRSP collects more revenue than its actual
net revenue requirement, CRSP will return this revenue through a credit
against a revenue requirement in a subsequent year. Actual revenues
that are less than the net revenue requirement would likewise be
recovered in a subsequent year. The true-up procedure will ensure that
CRSP will recover no more and no less than the actual transmission
costs for the year.
Data used in the annual recalculation of the formula rates each
year will be made available for review and comment, as described in the
Formula Rate Implementation Protocols (Protocols).
[[Page 30919]]
These Protocols ensure interested parties are aware of the data used to
calculate the formula rates and are provided the opportunity to comment
before the costs are collected through the formula rates.
The formula rate templates, and the Protocols will be posted on the
applicable SPP website and on CRSP's OASIS website.
Formula Rate for CRSP Annual Transmission Revenue Requirement--Rate
Schedule CRCMT-ATRR
For transmission service provided by SPP under SPP's Tariff, under
Rate Schedule CRCMT-ATRR, CRSP will use a formula-based rate
methodology to calculate its ATRR. The ATRR is derived by annualizing
CRSP's transmission investments that meet the Transmission Facility
criteria, as identified in Attachment AI to SPP's Tariff, and adding
transmission-related annual costs, which include O&M, administrative
and general expenses, interest, and depreciation. The annual costs will
be reduced by applicable revenue credits received by CRSP under the SPP
Tariff. CRSP will recover transmission-related expenses and investments
on a forward-looking basis by using projections to estimate
transmission costs for the upcoming rate year, with a true-up of
incurred costs in a subsequent year. CRSP will true up the cost
estimates it used in the calculation of its FY 2025 and FY 2026
transmission rates that were in place prior to joining SPP when
calculating these future true ups.
CRSP will provide its overall ATRR as separate subtotals to
distinguish CRSP transmission facilities between the CRSPZ and other
SPP Zones. SPP will utilize these ATRR subtotals, along with zonal and
regional load and other applicable information, to calculate the
applicable charges and revenue distribution for SPP transmission
service under the SPP Tariff.
Formula Rate for Scheduling, System Control, and Dispatch Service--Rate
Schedule CRCMT-AS1
Scheduling, System Control, and Dispatch (SSCD) Service is required
to operate a Transmission Owner's SPP Tariff facilities and to schedule
movement of power through, out of, within, or into one or both of the
SPP BAAs and certain parts of the transmission system not located
within a SPP BAA. These functions are conducted by the Rocky Mountain
region's (RMR) Operations staff on behalf of the Loveland Area Projects
and CRSP Transmission Owners. RMR will use a formula-based rate
methodology to calculate its annual revenue requirement (ARR) for SSCD
Service. RMR's overall ARR for SSCD Service is allocated between CRSP
and RMR. CRSP's transmission portion of its allocation of the SSCD ARR
will be collected under Rate Schedule CRCMT-AS1, and RMR's allocation
of the SSCD ARR will be collected by RMR under its applicable rate(s).
SPP will use CRSP's transmission portion of its allocation of the SSCD
Service ARR to determine the regional SPP Schedule 1 rate and revenue
distribution for SPP through-and-out transactions and to determine the
zonal SPP Schedule 1 rate and revenue distribution for the appropriate
zones under the SPP Tariff.
RMR's overall SSCD Service ARR is derived by calculating RMR's
applicable annual costs associated with the provision of SSCD Service,
including O&M, administrative and general expenses, interest, and
depreciation. Estimates are calculated on a forward-looking basis by
using projections to determine costs associated with SSCD Service for
the upcoming rate year, with a true-up of incurred costs in a
subsequent year. CRSP's portion of its allocation of the SSCD ARR will
be reduced by any applicable revenue received by CRSP under the SPP
Tariff.
Formula Rate Implementation Protocols
For transmission service and ancillary services provided under the
SPP Tariff, CRSP will provide information relating to CRSP's rate
implementation and annual update procedures and timelines in a
``Formula Rate Implementation Protocols'' document. The Protocols,
together with the above-mentioned formula rate templates, comprise the
Formula Rates that will be submitted to SPP to be incorporated in the
SPP Tariff. All relevant information pertaining to CRSP's annual
updates, customer notifications, review periods, and meeting
requirements will be contained in the Protocols. These notifications,
review periods, and meetings ensure interested parties are aware of the
data used to calculate the formula rates and are provided the
opportunity to comment before the costs are collected through the
formula rates.
CRSP Deliveries Into WALC BA--Rate Schedule CRCMT-PTP
For deliveries associated with certain CRSP Southern Division
customers located in WAPA's Western Area Lower Colorado (WALC)
Balancing Authority (BA), CRSP will retain a portion of its
transmission system from Glen Canyon to Pinnacle Peak. This portion of
CRSP transmission will remain under WAPA's functional control and will
be governed by WAPA's Tariff. Accordingly, this identified portion of
the CRSP transmission system will not be transferred to SPP's
functional control and will not be governed by SPP's Tariff.
Consistent with CRSP's current point-to-point transmission formula
rate under Rate Schedule SP-PTP10, CRSP will establish this point-to-
point ATRR using a formula-based rate methodology. The ATRR is derived
by annualizing CRSP's transmission investments and adding transmission-
related annual costs, which include O&M, administrative and general
expenses, interest, and depreciation. The annual costs will be reduced
by applicable revenue credits received by CRSP under WAPA's Tariff.
CRSP will continue to recover transmission-related expenses and
investments on a forward-looking basis by using projections to estimate
transmission costs for the upcoming year, with a true-up of incurred
costs in a subsequent year.
Comments
CRSP received 91 separate oral and written comments during the
public consultation and comment period. The comments expressed have
been paraphrased or combined where appropriate, without compromising
the meaning of the comments.
Comments on the Annual Transmission Revenue Requirement
A. Comment: A jointly submitted comment from several entities
expressed that while they understand the need for the WAPA-220 rate,
there are some ``fundamental concerns regarding how the [ATRR] will be
treated, based on comments made prior to issuance of the FRN.''
Response: CRSP appreciates this comment and the opportunity to
receive customer input through the public process. CRSP recognizes
commenters' concerns regarding allocation of costs and benefits
associated with potential RTO membership and addresses those comments
further below.
B. Comment: CRSP received various comments concerning costs and
benefits of RTO participation for customers electing to participate in
the Glen Canyon Allocator (Allocator). These comments state that
``[c]ost causation is a bedrock principle in the energy industry, and
the implication that SPP start-up and ongoing costs for the SPP system
will be included in the ATRR violates this principle if those costs
would apply to the Allocator customers as well.'' Also, ``[i]t remains
fundamentally important from a cost
[[Page 30920]]
causation perspective that the costs of implementing and operating the
CRSP system for the benefit of SPP members be recovered in the formula
that WAPA will develop through WAPA-220.'' In addition, ``beneficiaries
should pay for the costs of the SPP market integration and
implementation.'' Further: ``While the idea of socializing the costs
and benefits of the transmission system may be well intended, we
disagree with the proposal because of the violation of cost causation.
As such, we would not expect WAPA-220 to include the Allocator costs,
nor should the Allocator customers benefit from utilization of the CRSP
system in SPP.''
Response: CRSP appreciates these comments. Currently, any costs
associated with SPP start-up and ongoing market participation will be
included in CRSP's firm electric service (FES) rate and not the ATRR
associated with the transmission and ancillary service rates involved
in this rate action. CRSP will continue to engage with customers in
future FES rate processes to address issues surrounding the costs and
benefits of RTO participation. CRSP notes, however, that it currently
serves all FES customers through a cost-based bundled FES rate that is
the lowest possible consistent with sound business principles. CRSP has
determined that pursuing RTO membership is consistent with these
requirements and its statutory authorities. CRSP looks forward to
working with customers on future FES rate design and remains open to
alternate rate designs.
Comments on the Glen Canyon Allocator
A. Comment: A jointly submitted comment from several entities
states: ``We appreciate that WAPA has accommodated the portion of Lower
Division customers who initially requested a pseudo-tie, even improving
that idea with the Allocator concept. The Allocator would carve out a
section of transmission line, which would not be included in the SPP
RTO, so those customers should not be subject to any costs associated
with the SPP RTO. The FRN specifically states that the transmission
system not included in the SPP RTO (Allocator) will not be governed by
SPP's tariff. Those who have elected to use the [A]llocator consider
SPP entry and administrative costs associated with that tariff.''
Response: CRSP understands that some customers would prefer not to
be subject to any costs or benefits associated with CRSP's proposed
participation in the SPP RTO. CRSP disagrees that electing to
participate in the Glen Canyon Allocator automatically warrants a
separate rate for the service that participants receive from an
integrated federal project. CRSP is currently engaging customers about
aligning costs and benefits in the FES rate and will continue to engage
customers on appropriate steps moving forward.
B. Comment: A comment noted that the FRN proposing the rate
adjustments referenced a ``Pseudo-Tie'' in three locations and stated
the commenter's understanding that CRSP had moved past this concept in
favor of the Glen Canyon Allocator concept.
Response: CRSP appreciates this comment and agrees that the Glen
Canyon Allocator accurately captures the concept and arrangements in
question. CRSP has updated the WAPA-220 Final Rate Order documents to
reference the Allocator arrangements rather than a pseudo-tie.
C. Comment: A comment seeks to ``ensure that implementation of the
Glen Canyon Allocator will not leave the WALC BA responsible for
delivering all CRSP/SLCAIP Firm Electric Service at CROD without
adequate transmission entitlements.'' To this end, commenter
``believe[s] that the WAPA facilities incorporated in the Glen Canyon
Allocator should also extend from the Glen Canyon Dam east to Shiprock
Substation in order to ensure the firmness of Firm Electric Service
deliveries through the Glen Canyon Allocator in the event of an outage
of the WAPA Glen Canyon-Pinnacle Peak system.'' The comment further
notes ``[t]his extension of the Allocator to Shiprock should also
enable WAPA DSW-based contractors to continue to access resources at
the Shiprock hub under WAPA's agreements with neighboring utilities for
firming resources for their SCLA/IP entitlements--whether by WAPA to
firm DSA, SHP, or CROD; or by the customers as CDP firming replacement
power as defined in the SCLA/IP Agreements.''
Response: CRSP appreciates this comment. On April 28, 2023, WAPA
published a Proposed FRN (88 FR 26298) recommending that, along with
other regional offices of WAPA, CRSP pursue final negotiations
regarding participation in the SPP RTO. Discussions and information
about the proposal of what would become the Glen Canyon Allocator were
covered extensively as part of the associated public process, including
a public meeting on June 27, 2023, specifically addressing that topic,
as well as extension of the public comment period to directly address
issues surrounding CRSP's potential participation in the SPP RTO.
Although the proposed extension of the Glen Canyon Allocator facilities
is outside the scope of the WAPA-220 rate process, CRSP looks forward
to continuing to work with its FES customers to address ongoing
concerns related to FES deliveries and implementation of the Glen
Canyon Allocator.
D. Comment: A commenter states: ``The formula for the Glen Canyon
Allocator ATRR should follow the transmission facilities use and
usefulness in the WALC BAA and their ATRRs should be combined under the
One Transmission Rate established under Rate Order WAPA-209.'' Further,
``[u]sing the Rate Order WAPA-209 One Transmission Rate to recover
WAPA's costs relating to the Glen Canyon Allocator would eliminate
point-to-point transmission rate pancaking for delivery of CRSP/SLCAIP
entitlements to DSW-based contractors, which [commenter] had understood
to be an objective of adopting the WAPA-209 One Transmission Rate and
moving WAPA to flow-based transmission services as encouraged by the
FERC.''
Response: CRSP appreciates this comment but considers proposals to
modify Rate Order WAPA-209 are outside the scope of this WAPA-220 rate
process. CRSP looks forward to continuing to work with its customers to
address matters related to implementing the Glen Canyon Allocator.
E. Comment: A commenter states ``it would be helpful if CRSP were
to outline the process through which CRSP, the SPP, RTO West and other
proponents of the RTO-West initiative have engaged with neighboring
BAAs . . . concerning the operational impacts of CRSP's RTO-West
proposal.''
Response: SPP is now working with transmission planning and
engineering staff at electric utilities neighboring CRSP on operational
issues related to ``seams'' (where different utilities are
interconnected), as well as coordinated operation of jointly owned
transmission lines, including parallel path operations. These seams-
related issues will be vetted through SPP's established stakeholder
processes.
F. Comment: A jointly submitted comment from several entities
states: ``The portion of the transmission system that won't be included
in the SPP RTO (Allocator) will still be under the WAPA-206 rate case;
however, the FRN for the WAPA-220 case alludes to modifying the WAPA-
206 rate case. Shouldn't any substantial changes to WAPA-206 initiate a
new rate case. We would consider inclusion of cost not previously
considered, like the SPP
[[Page 30921]]
entry and maintenance costs, to necessitate a new rate case.''
Response: Should CRSP enter the SPP RTO, applicable SPP RTO and
Glen Canyon Allocator costs will be included in the CRSP Power
Repayment Study (PRS). The PRS is run twice a year (Preliminary and
Final) for rate sufficiency. Should these costs, or any other rate-
impacting activities result in a significant rate impact (either an
increase or decrease), it could result in a rate adjustment process.
CRSP also notes Rate Schedule CRCMT-PTP discussed in this Rate Order
will supersede Rate Schedule SP-PTP10 established in WAPA-206.
Comments Pertaining To Scheduling, System Control, and Dispatch Service
A. Comment: Citing historic practices, a commenter states: ``CRSP
should ``include in the Allocator portions of the ancillary services
and quantify such to the WALC BAA for compliance with WECC and NERC to
effectuate the delivery and BAA obligations of WAPA to BAAs and SLCA/IP
contractors outside the RTO West.''
Response: CRSP is actively engaged and will continue to work with
its FES customers outside this rate process to implement FES deliveries
under the Glen Canyon Allocator. Implementation of ancillary services
and transmission arrangements for the Glen Canyon Allocator portions
have been negotiated, and implementation is currently ongoing with
customers and with WAPA's staff in the Desert Southwest regional
office.
B. Comment: A commenter requested that CRSP clarify the scheduling
procedures of the CRSP hydropower allocation with CRSP transferring
control of its eligible transmission facilities to SPP. Commenter notes
proposed rate schedule CRCMT-AS1 identifies that SSCD Service will
shift away from current WAPA Operations staff to SPP.
Response: CRSP anticipates that scheduling procedures currently
used by customers for the delivery of CRSP hydropower allocations will
remain the same as today. If CRSP identifies that any changes are
needed, an updated Scheduling, Accounting, and Billing Procedure
document will be provided to each customer.
Comments Pertaining to the Rate Implementation Protocols
A. Comment: A commenter recommended that posting date(s) should be
``not later than'' as opposed to ``on or around.'' The comment notes
``or around'' could result in a case of a challenge needing to be filed
within a minimum number of days after the posting.
Response: The reference to ``on or around'' is meant to account for
holidays, weekends, or other situations where the actual posting on the
1st or 15th of the month is not possible.
B. Comment: A commenter would like CRSP to consider using a ``not
later than'' and number of days following the ``Posting Date.''
Alternatively, commenter recommended CRSP consider adding a sentence
stating: ``In no event shall the Review Period be not less than 65
days.'' Commenter noted this number is ten less than the anticipated
draft schedule.
Response: CRSP appreciates the comment and will consider that
verbiage for future public processes.
C. Comment: A commenter requested that CRSP consider revising
``requesting party(ies)'' to ``Interested Party(ies).''
Response: ``Requesting parties'' is used to identify ``interested
parties'' who executed a confidentiality agreement with CRSP to view
information deemed by CRSP to be confidential.
D. Comment: A commenter asked CRSP to clarify the definition of
CRSP as the SPP Transmission Customer to include ``FES'' or ``WAPA
Transmission Service customer.''
Response: CRSP does not believe it is necessary to include ``FES''
or ``WAPA Transmission Service Customer'' in the ``Interested Party''
definition. Per the Protocols, ``Customer(s)'' or ``Transmission
Customer(s)'' means the customers taking Network Integration
Transmission Service under Grandfathered Agreements, or (``PTP'')
Transmission Service.
E. Comment: Recognizing the timetables assumed in the FRN, and the
potential for changes in those timetables, a commenter recommends the
WAPA-220 documentation include a statement that approval of WAPA-220 by
the Administrator, rather than by FERC, should be sufficient to provide
SPP to meet its October 2025 filing deadline.
Response: CRSP agrees that the Administrator's approval is
sufficient to confirm, approve, and place the rate into effect on an
interim basis. However, CRSP intends to request that FERC confirm and
approve its rates on a final basis prior to October 2025 to align with
SPP's implementation timeline.
Comments on Public Process
A. Comment: A commenter expressed, as a general matter, support for
CRSP's WAPA-220 rate schedules and appreciation for CRSP's efforts
regarding the Federal Service Exemption as CRSP considers participation
in the SPP RTO. Commenter also indicated it was evident from the
customer discussions that market and cost/rate-related topics outside
the scope of this proceeding support CRSP's continuance of monthly
customer forums, and commenter appreciates CRSP scheduling those
discussions.
Response: CRSP appreciates these comments.
B. Comment: A commenter appreciates the communication provided in
the WAPA-220 Information and Comment Forums and additional customer
meetings held in February and March and for providing an opportunity
for further questions and comments and anticipates participating in any
future discussion forums.
Response: CRSP appreciates customer participation in its public
processes.
C. Comment: A commenter noted ``[g]iven the complexity of these
issues, we suggest that you release the formula rates one week prior to
any Public Information Forums in the future. That would allow us time
to review and be fully prepared to discuss during a Public Comment
Forum. It is difficult to see the proposed rates and then be expected
to ask clarifying questions one hour after first seeing them.''
Response: CRSP appreciates this comment and will take it into
consideration for future rate processes.
D. Comment: A commenter stated, ``Please consider bifurcating the
Information and Comment Forums to allow a minimum of one week for
customers to digest the information provided at the [Information Forum]
. . . . Alternatively, please consider scheduling a second Comment
Forum.''
Response: CRSP appreciates this recommendation and will consider
this practice for future public processes. However, considering the
date established in the Proposed WAPA-220 FRN, publishing notice of a
change or additional Public Comment Forum may have resulted in CRSP not
having adequate time to meet all the necessary requirements for the
proposed April 1, 2026, SPP RTO go-live date.
E. Comment: A jointly submitted comment from several entities
stated: ``Given that the WAPA-220 case won't take effect until April 1,
2026 (at the earliest), we recommend that WAPA takes its time to ensure
that the transmission rates work for all parties.''
Response: CRSP seeks to align the timing of this rate process with
SPP implementation and filing timelines while also adhering to
Department of Energy timelines for public processes to establish
service rates. While this rate process seeks approval on the formula
[[Page 30922]]
used to establish the formula rates, as described in the Formula Rate
Implementation Protocols, data used in the annual recalculation of the
formula rates each year will be made available for review and comment.
These Protocols ensure interested parties are aware of the data used to
calculate the formula rates and are provided the opportunity to comment
before the costs are collected through the formula rates.
Other Comments
A. Comment: A commenter states: ``The benefit analysis that appears
to be driving this decision shows the possibility for both a positive
and negative outcome. Given the uncertainty of what could happen to the
WAPA-220 (and WAPA-206) rate(s), we suggest that you shorten this rate
window from five years to two years. That will give CRSP and customers
time to evaluate this new paradigm and see how the rate settles out.''
Response: CRSP believes a five-year rate is preferable to gather
sufficient data to support future rate analysis and development. Given
the time required to establish a new rate through a public process, a
two-year rate would require CRSP to initiate a new rate process
relatively soon after beginning market participation and with limited
empirical data.
B. Comment: A commenter wanted confirmation that economically
offered hydropower will not interfere, impact, or reduce the Renewable
Energy Certificates (RECs) associated with the seasonal sustainable
hydropower sales amount.
Response: Hydropower deliveries are a function of water release
schedules and water delivery obligations. Customers will continue to
receive power and energy from hydropower resources without interfering
with the RECs associated with those deliveries.
Certification of Rates
I have certified that the Provisional Formula Rates for Colorado
River Storage Project transmission and ancillary service under Rate
Schedules CRCMT-ATRR, CRCMT-AS1, and CRCMT-PTP are the lowest possible
rates, consistent with sound business principles. The Provisional
Formula Rates were developed following administrative policies and
applicable laws.
Availability of Information
Information used by CRSP to develop the Provisional Formula Rates
is available for inspection and copying at the CRSP Regional Office,
1800 South Rio Grande Avenue, Montrose, CO. Many of these documents are
also available on CRSP's Rates website previously listed.
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 part
1021: B4.3 (Electric power marketing rate changes).\4\ Categorically
excluded projects and activities do not require preparation of either
an environmental impact statement or an environmental assessment. A
copy of the categorical exclusion determination is available on DOE's
website at <a href="http://www.energy.gov/nepa/categorical-exclusion-determinations-western-area-power-administration-colorado-river-storage">www.energy.gov/nepa/categorical-exclusion-determinations-western-area-power-administration-colorado-river-storage</a>.
---------------------------------------------------------------------------
\4\ The determination was done in compliance with NEPA (42
U.S.C. 4321-4347) 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 Formula 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-220. 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 July 7,
2025, 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 July 9, 2025.
Jennifer Hartzell,
Alternate Federal Register Liaison Officer, U.S. Department of Energy.
Rate Schedule CRCMT-ATRR
United States Department of Energy
Western Area Power Administration
Colorado River Storage Project Region
Colorado River Storage Project
Annual Transmission Revenue Requirement for Transmission Service
(Approved Under Rate Order No. WAPA-220)
Effective
The first day of the first full billing period beginning on the
later of the following events: (1) when the Western Area Power
Administration-Colorado River Storage Project (WAPA-CRSP) region
officially becomes a member of, and transfers functional control of
Colorado River Storage Project (CRSP) transmission facilities to the
Southwest Power Pool (SPP), or (2) the go-live date of the expansion of
the SPP Regional Transmission Organization (RTO) into the Western
Interconnection (scheduled for April 1, 2026, as of date of the
approved Rate Order) and extending through March 31, 2031, or until
superseded by another rate schedule, whichever occurs earlier.
Notification of the actual effective date will be posted on WAPA-CRSP's
Rates website and on WAPA-CRSP's Open Access Same-Time Information
System (OASIS) website.
Applicable
WAPA-CRSP's formula based Annual Transmission Revenue Requirement
(ATRR) for its eligible transmission-related facilities included under
the SPP Open Access Transmission Tariff (Tariff) will be separated
between (1) CRSP's Western Interconnection transmission facilities and
(2) CRSP's transmission facilities determined to be in other SPP RTO
transmission pricing zones. Each ATRR subtotal will be calculated using
the formula outlined below.
Formula Rate
Define
A = Operation & Maintenance Expense allocated to transmission ($)
[[Page 30923]]
B = Administrative and General Expense allocated to transmission ($)
C = Depreciation Expense allocated to transmission ($)
D = Interest Expense allocated to transmission ($)
E = Applicable ratio share of plant for CRSP's Western Interconnection
transmission facilities and CRSP transmission facilities determined to
be in other SPP RTO transmission pricing zones (%)
F = Revenue Credits--Scheduling, System Control, and Dispatch service
associated with each specific ATRR subtotal ($)
G = Revenue Credits associated with each specific ATRR subtotal ($)
H = Prior Period True-up associated with each specific ATRR subtotal
($)
ATRR Subtotals = ((A + B + C + D) * E)-F-G + H
Total ATRR = Sum of all ATRR Subtotals
Note: WAPA-CRSP will identify any portion(s) of the ATRR eligible
for recovery under SPP Schedule 9 and Schedule 11 pursuant to the SPP
Tariff in its Rate Formula Template submitted under Attachment H of the
SPP Tariff.
A recalculated ATRR will go into effect every January 1 based on
the above formula and updated financial data. WAPA-CRSP will annually
notify SPP and make data and information available to interested
parties for review and comment related to the recalculated ATRR on or
shortly after September 1 of the preceding year. This data and
information will be posted on the applicable SPP website and on WAPA-
CRSP's OASIS website.
Rate Schedule CRCMT-AS1
United States Department of Energy Western Area Power Administration
Colorado River Storage Project Region
Colorado River Storage Project
Scheduling, System Control, and Dispatch Service
(Approved Under Rate Order No. WAPA-220)
Effective
The first day of the first full billing period beginning on the
later of the following events: (1) when the Western Area Power
Administration--Colorado River Storage Project (WAPA-CRSP) region
officially becomes a member of, and transfers functional control of
Colorado River Storage Project (CRSP) transmission facilities to, the
Southwest Power Pool (SPP); or (2) the go-live date of the expansion of
the SPP Regional Transmission Organization (RTO) into the Western
Interconnection (scheduled for April 1, 2026, as of date of the
approved Rate Order) and extending through March 31, 2031, or until
superseded by another rate schedule, whichever occurs earlier.
Notification of the actual effective date will be posted on WAPA-CRSP's
Rates website and on WAPA-CRSP's Open Access Same-Time Information
System (OASIS) website.
Applicable
Scheduling, System Control, and Dispatch Service (SSCD) is required
to schedule the movement of power through, out of, within, or into one
or both of the SPP Balancing Authority Areas (BAA) and certain parts of
the transmission system not located within an SPP BAA. WAPA-CRSP's
annual revenue requirement (ARR) for SSCD will be separated between
service provided for CRSP transmission facilities in the CRSP Zone
(CRSPZ or Zone 103) and for CRSP transmission facilities determined to
be in other SPP RTO transmission pricing zones. The ARR and ARR
subtotals will be calculated using the formula outlined below.
Formula Rate
Define
A = Operation & Maintenance Expense for SSCD ($)
B = Administrative and General Expense for SSCD ($)
C = Depreciation Expense for SSCD ($)
D = Interest Expense for SSCD ($)
E = Prior Period True-up ($)
F = Applicable ratio share of plant for CRSPZ and for other SPP RTO
transmission pricing zones (%)
SSCD ARR = (A + B + C + D + E)
ARR Subtotals = (SSCD ARR) * F
A recalculated ARR will go into effect every January 1 based on the
above formula and updated financial data. WAPA-CRSP will annually
notify SPP and make data and information available to interested
parties for review and comment related to the recalculated ARR on or
shortly after September 1 of the preceding year. This data and
information will be posted on the applicable SPP website and on WAPA-
CRSP's OASIS website.
Rate Schedule CRCMT-PTP
Schedule 7 to Tariff
(Supersedes Schedule SP-PTP10)
United States Department of Energy
Western Area Power Administration
Colorado River Storage Project Region
Colorado River Storage Project
Firm Point-to-Point Transmission Service
(Approved Under Rate Order No. WAPA-220)
Effective
The first day of the first full billing period beginning on the
later of the following events: (1) when the Colorado River Storage
Project (CRSP) region officially becomes a member of, and transfers
functional control of CRSP transmission facilities to, the Southwest
Power Pool (SPP); or (2) the go-live date of the expansion of the SPP
Regional Transmission Organization into the Western Interconnection
(scheduled for April 1, 2026, as of date of the approved Rate Order)
and extending through March 31, 2031, or until superseded by another
rate schedule, whichever occurs earlier. Notification of the actual
effective date will be posted on CRSP's Rates website and on the
Western Area Lower Colorado (WALC) Open Access Same-Time Information
System (OASIS) website.
Applicable
Rate Schedule CRCMT-PTP is applicable only to those customers who
purchase CRSP transmission service under the Western Area Power
Administration (WAPA) Open Access Transmission Tariff (OATT).
The Transmission Customer will compensate CRSP 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] TN11JY25.003
[[Page 30924]]
A recalculated rate will go into effect every January 1 based on
the above formula and updated financial and operational data. CRSP will
notify the transmission customer annually and make data and information
available to interested parties for review and comment related to the
recalculated rate on or shortly after September 1 of the preceding
year. This data and information will be posted on CRSP's Rates website
and on WALC's OASIS website. Discounts may be offered from time to time
in accordance with WAPA's OATT.
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
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.
[FR Doc. 2025-12994 Filed 7-10-25; 8:45 am]
BILLING CODE 6450-01-P
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</html>Indexed from Federal Register on July 11, 2025.
This is legal information, not legal advice. Laws vary by jurisdiction and change frequently. Always verify current law with official sources and consult a licensed attorney in your jurisdiction for advice on your specific situation.