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Notice2024-16029

Central Valley Project/Power, Transmission, and Ancillary Services and California-Oregon Transmission Project Transmission Service-Rate Order No. WAPA-207

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 22, 2024

Effective

October 1, 2024

Issuing agencies

Energy DepartmentWestern Area Power Administration

Abstract

The formula rates for the Sierra Nevada Region (SN) Central Valley Project (CVP) power, transmission, and ancillary services and California-Oregon Transmission Project (COTP) transmission service have been confirmed, approved, and placed into effect on an interim basis. These new formula rates replace the existing formula rates which expire on September 30, 2024, and December 31, 2024. There are no changes to the existing formula rates for these services and there are no material changes aside from updating the effective dates.

Full Text

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<title>Federal Register, Volume 89 Issue 140 (Monday, July 22, 2024)</title>
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[Federal Register Volume 89, Number 140 (Monday, July 22, 2024)]
[Notices]
[Pages 59082-59097]
From the Federal Register Online via the Government Publishing Office [<a href="http://www.gpo.gov">www.gpo.gov</a>]
[FR Doc No: 2024-16029]

[[Page 59082]]

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DEPARTMENT OF ENERGY

Western Area Power Administration

Central Valley Project/Power, Transmission, and Ancillary
Services and California-Oregon Transmission Project Transmission
Service--Rate Order No. WAPA-207

AGENCY: Western Area Power Administration, Department of Energy (DOE).

ACTION: Notice of rate order concerning power, transmission, and
ancillary services formula rates.

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SUMMARY: The formula rates for the Sierra Nevada Region (SN) Central
Valley Project (CVP) power, transmission, and ancillary services and
California-Oregon Transmission Project (COTP) transmission service have
been confirmed, approved, and placed into effect on an interim basis.
These new formula rates replace the existing formula rates which expire
on September 30, 2024, and December 31, 2024. There are no changes to
the existing formula rates for these services and there are no material
changes aside from updating the effective dates.

DATES: The Provisional Formula Rates under Rate Schedules CV-F14, CPP-
3, CV-T4, CV-NWT6, COTP-T4, CV-TPT8, CV-UUP2, CV-SPR5, CV-SUR5, CV-
RFS5, CV-EID6, CV-GID3, CV-SSP3, CV-EIM1S1, CV-EIM4S1, and CV-EIM9S1
are effective on the first day of the first full billing period
beginning on or after October 1, 2024, and will remain in effect
through September 30, 2029, pending confirmation and approval by the
Federal Energy Regulatory Commission (FERC) on a final basis or until
superseded.

FOR FURTHER INFORMATION CONTACT: Michelle Williams, Regional Manager,
Sierra Nevada Region, Western Area Power Administration, 114 Parkshore
Drive, Folsom, CA 95630, or Autumn Wolfe, Rates Manager, Sierra Nevada
Region, Western Area Power Administration, (916) 353-4686, or email:
<a href="/cdn-cgi/l/email-protection#0e5d405c235c6f7a6b4d6f7d6b4e796f7e6f20696178"><span class="__cf_email__" data-cfemail="174459453a4576637254766472576076677639707861">[email&#160;protected]</span></a>.

SUPPLEMENTARY INFORMATION: On December 2, 2011, FERC confirmed and
approved Rate Schedules for CVP power, transmission, and ancillary
services; COTP transmission; and Pacific Alternating Current Intertie
(PACI) transmission under Rate Order No. WAPA-156. That rate order was
extended by Rate Order Nos. WAPA-173 and WAPA-185. These rates are set
to expire on September 30, 2024.\1\ The formula rate schedules are:
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\1\ See Docket No. EF11-9-00 (137 FERC ] 62,201) (2011).
Extended by Docket No. EF16-3-000 (156 FERC ] 62,039) (2016).
Extended by Docket No. EF19-4-000 (168 FERC ] 62,150) (2019).

<bullet> CV-F13 Base Resource and First Preference Power
<bullet> CPP-2 Custom Product Power
<bullet> CV-T3 Firm and Non-Firm Point-to-Point Transmission Service
<bullet> CV-NWT5 Network Integration Transmission Service
<bullet> COTP-T3 Firm and Non-Firm Point-to-Point Transmission Service
<bullet> PACI-T3 Firm and Non-Firm Point-to-Point Transmission Service
(to be handled in a separate rate case)
<bullet> CV-TPT7 Third-Party Transmission Service
<bullet> CV-UUP1 Unreserved Use Penalties
<bullet> CV-RFS4 Regulation and Frequency Response
<bullet> CV-SPR4 Spinning Reserves
<bullet> CV-SUR4 Supplemental Reserves

On April 27, 2021, FERC confirmed and approved Rate Order No. WAPA-
194, which placed into effect formula rates for the Energy Imbalance
Market (EIM) services, Sale of Surplus Products, and revisions to
existing rate schedules for Energy Imbalance and Generator Imbalance
services. These rates are being superseded as they were not set to
expire until December 31, 2024.\2\ The formula rate schedules are:
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\2\ See Docket No. EF21-1-000 (86 FERC ] 11760) (2021).

<bullet> CV-EIM1S EIM Administrative Service Charge
<bullet> CV-EIM4S EIM Energy Imbalance Service
<bullet> CV-EIM9S EIM Generator Imbalance Service
<bullet> CV-SSP2 Sale of Surplus Products
<bullet> CV-EID5 Energy Imbalance Service
<bullet> CV-GID2 Generator Imbalance Service

Western Area Power Administration (WAPA) published a Federal
Register notice (Proposed FRN) on August 30, 2023 (88 FR 59909),
proposing new formula rates for CVP power, transmission, and ancillary
services and COTP transmission service. The Proposed FRN also initiated
a 90-day public consultation and comment period (which was subsequently
extended another 30-days) \3\ and set forth the date and location of
the public information and public comment forums. The rates continue
the formula-based methodology that includes an annual update to the
financial, load, and other data in the rate formulas.
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\3\ 88 FR 80293 (Nov. 17, 2023).
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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-SN 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 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 review of WAPA-SN's proposal, Rate Order No. WAPA-207,
which provides the formula rates for CVP power, transmission, and
ancillary services and COTP transmission service, is hereby confirmed,
approved, and placed into effect on an interim basis. WAPA-SN will
submit Rate Order No. WAPA-207 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, Sierra Nevada
Region, Rate Adjustment for the Central Valley Project Power,
Transmission, and Ancillary Services; and California-Oregon
Transmission Project Transmission Service Formula Rates, Rate Order No.
WAPA-207

Order Confirming, Approving, and Placing the Formula Rates for Central
Valley Project and California-Oregon Transmission Project Into Effect
on an Interim Basis

The formula rates in Rate Order No. WAPA-207 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 other acts that specifically apply to the projects
involved.

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[[Page 59083]]

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.\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:
BA: As defined in WAPA's Open Access Transmission Tariff (OATT), is
Balancing Authority and is the responsible entity that integrates
resource plans ahead of time, maintains load Interchange-generation
balance within a Balancing Authority Area, and supports interconnection
frequency in real time.
BAA: As defined in WAPA's OATT, is Balancing Authority Area; the
term Balancing Authority Area shall have the same meaning as ``Control
Area.''
BANC: Balancing Authority of Northern California is a joint powers
authority that provides BA and other services to its members and other
entities within the BAA. Members/entities of BANC may in turn provide
transmission service to customers.
BR: Base Resource, as defined in Central Valley Project's 2025
Marketing Plan is the Central Valley and Washoe Project power (capacity
and energy) output determined by WAPA-SN to be available for marketing,
including the environmental attributes, after meeting the requirements
of project use and first preference customers, and any adjustments for
maintenance, reserves, system losses, and certain ancillary services.
CAISO: As defined in WAPA's OATT, is the California Independent
System Operator. A state-chartered, California, non-profit public
benefit corporation that operates the transmission facilities of all
CAISO participating transmission owners and dispatches certain
generating units and loads. The CAISO is the Market Operator (MO) for
the EIM.
Capacity: The electric capability of a generator, transformer,
transmission circuit, or other equipment. It is expressed in kilowatts
(kW) or megawatts (MW).
Conforming Load: The term is not officially defined by CAISO at
this time and will be addressed in the future. The following
description reasonably aligns with the CAISO's use of the term in
defining load forecasting requirements under EIM: it is the load that
changes in a reasonably predictable, uniform manner that is
environmentally driven. A conforming load has a load profile that is
similar to the aggregated load profile. Due to conventional weather-
and temperature-based patterns, conforming loads can be forecast with a
high level of accuracy using historical and meteorological data.
CVP: As defined in Central Valley Project's 2025 Marketing Plan, is
Central Valley Project. The multipurpose Federal water development
project extending from the Cascade Range in northern California to the
plains along the Kern River south of the city of Bakersfield,
California.
EI Service: Energy Imbalance Service is an ancillary service that
provides for the difference between the scheduled and the actual
delivery of energy to a load within the Transmission Provider's Sub-
BAA.
EIM: As defined in CAISO's Business Practice Manual, means Energy
Imbalance Market and is the rules and procedures in Section 29 of the
CAISO Tariff governing the CAISO's operation of the Real-Time Market in
BAAs outside of the CAISO BAA and the participation of EIM Market
Participants in the Real-Time Market.
EIM Administrative Charge: As defined in CAISO's Business Practice
Manual, is the fee imposed on transaction in the energy imbalance
market as described in section 29.11(i)(1) of the CASIO Tariff.
EIM Entity: As defined in WAPA's OATT, Attachment S, is a BAA that
enters into the MO's EIM Entity Agreement to enable the EIM to occur in
its BAA. BANC is the EIM Entity for the BANC EIM Entity BAA. For the
purposes of this Attachment S, the EIM Entity is the BANC EIM Entity,
or the entity selected by the BANC EIM Entity who is certified by the
MO. WAPA-SN participates in the CAISO EIM under the BANC EIM Entity.
EIM Non-Participating Resource: As defined on CAISO's website: EIM
Resource that does not participate in the Real-Time Market but is
required to be identified in the EIM BAA for settling charges and
payments related to nonparticipating load and nonparticipating
resources.
EIM Participating Resource: As defined in WAPA's OATT, Attachment
S, is a resource or a portion of a resource: (1) that meets the
Transmission Provider's eligibility requirements; (2) has been
certified by the BANC EIM Entity for participation in the EIM; and (3)
for which the generation owner and/or operator enters into the MO's EIM
Participating Resource Agreement and any agreements as may be required
by BANC and/or the BANC EIM Entity.
EIM Participating Resource Scheduling Coordinator: As defined in
WAPA's OATT, Attachment S, an entity with one or more BANC EIM
Participating Resource(s) or a third-party designated by the
Transmission Customer with one or more BANC EIM Participating
Resource(s), that is certified by the MO and enters into the MO's EIM
Participating Resource Scheduling Coordinator Agreement.
Energy: As defined in Central Valley Project's 2025 Marketing Plan,
is measured in terms of the work it is capable of doing over a period
of time; electric energy is usually measured in kilowatt-hours or
megawatt-hours.
Firm Point-To-Point Transmission Service: As defined in WAPA's
OATT, is transmission service reserved and/or scheduled between
specified Points of Receipt and Delivery pursuant to Part II of the
Tariff.
First Preference Customers/Entity: As defined in Central Valley
Project's 2025 Marketing Plan, is a preference customer and/or a
preference entity (an entity qualified to use, but not using,
preference power) within a country or origin (Trinity, Calaveras, and
Tuolumne) as specified under the Trinity River Division Act (69 Sta.
719) and the New Melones Project provisions of the Flood Control Act of
1962 (76 Stat. 1173, 1191-1192).

[[Page 59084]]

FRR: Frequency Response Reserve, as defined in Sacramento Municipal
Utility District's (SMUD's) Operating Reserves OP-114, ``NERC/WECC does
not have an official definition for Frequency Response Reserve (FRR)
yet. BANC is defining the FRR as an amount of reserve in MW that is
synchronized to the system and can automatically respond to system
frequency deviation. BANC in coordination with WAPA-SN and SMUD
procures and monitors sufficient FRR in both Day-Ahead scheduling
process and Real-Time operations to ensure that BANC meets NERC
Reliability Standard BAL0031.1 R1.''
FY: WAPA's fiscal year, October 1 to September 30.
Generating Unit: As defined in CAISO Tariff, is an individual
electric generator and its associated plant and apparatus whose
electrical output is capable of being separately identified and metered
or a Physical Scheduling Plant that, in either case, is: located within
the CAISO BAA (which includes a Pseudo-Tie of a generating unit to the
CAISO BAA) or, for purposes of scheduling and operating the Real-Time
Market only, an EIM Entity BAA; connected to the CAISO Controlled Grid,
either directly or via interconnected transmission, or distribution
facilities or via a Pseudo-Tie; and capable of producing and delivering
net energy (energy in excess of a generating station's internal power
requirements).
GI Service: Generator Imbalance Service is an ancillary service
that provides for the difference between the output of a generator and
the delivery schedule from that generator to: (1) another BAA, (2) the
BANC BAA, or (3) a load within the Transmission Provider's Sub-BAA. GI
Service during EIM participation is that associated with a generator
that is not an EIM Participating Resource located in the Transmission
Provider's Sub-BAA.
kW: Kilowatt--the electrical unit of capacity that equals 1,000
watts.
LAP: Load Aggregation Point is a set of Pricing Nodes as specified
in Section 27.2 of the CAISO Tariff that are used for the submission of
Bids and Settlement of Demand.
Load Ratio Share: As defined in WAPA's OATT, is the ratio of a
Transmission Customer's Network Load to the Transmission Provider's
total load computed in accordance with Sections 34.2 and 34.3 of the
Network Integration Transmission Service under Part III of the Tariff
and calculated on a rolling twelve-month basis.
Long-Term Firm Point-to-Point Transmission Service: As defined in
WAPA's OATT, is Firm Point-to-Point Transmission Service under Part II
of the Tariff with a term of one year or more.
MO: As defined in WAPA's OATT, Attachment S, is Market Operator.
The entity responsible for operation, administration, settlement, and
oversight of the EIM. The CAISO is the current MO of the EIM.
MO Tariff: As defined in WAPA's OATT, Attachment S, is those
portions of the MO's approved tariff, as such tariff may be modified
from time to time, that specifically apply to the operation,
administration, settlement, and oversight of the EIM.
NERC: The North American Electric Reliability Corporation.
New Rate: As defined in WAPA's OATT, means the modification of a
rate for transmission or ancillary services provided by the
Transmission Provider which has been promulgated pursuant to the rate
development process outlined in Power and Transmission Rates, 10 CFR
part 903 (2006).
NITS: Network Integration Transmission Service, as defined in
WAPA's OATT, is the transmission service provided under Part III of the
Tariff.
Non-conforming Load: The term is not officially defined by CAISO at
this time and will be addressed in the future. The following
description reasonably aligns with the CAISO's use of the term in
defining load forecasting requirements under EIM: it is the load with
unpredictable load pattern, e.g., pumps, industrial plants, etc., that
makes it difficult for the CAISO model to accurately forecast. CAISO's
load forecasting model uses historical actual conforming load data and
meteorological data determined necessary to accurately forecast the
conforming load. When non-conforming load causes more than 5% deviation
(hourly) from the total actual load, it should be modeled separately
from the load that CAISO will forecast for the EIM Entity (the
conforming load). This requirement is part of the EIM Readiness
Criteria in accordance with CAISO Tariff section 29.2(b)(7)(A)(iv).
Non-Firm Point-to-Point Transmission Service: As defined in WAPA's
OATT, is Point-to-Point Transmission Service under the Tariff that is
reserved and scheduled on an as-available basis and is subject to
Curtailment or Interruption as set forth in Section 14.7 under Part II
of the Tariff. Non-Firm Point-to-Point Transmission Service is
available on a stand-alone basis for periods ranging from one hour to
one month. The Transmission Provider may offer Non-Firm Point-to-Point
Transmission Service for periods longer than one month. If offered, the
terms and conditions will be consistent with Part II of the Tariff and
will be posted on the Transmission Provider's OASIS.
OASIS: As defined in WAPA's OATT, is Open Access Same-Time
Information System. The information system and standards of conduct
contained in Part 37 of FERC's regulations and all additional
requirements implemented by subsequent FERC orders dealing with OASIS.
OATT: The Open Access Transmission Tariff, including all schedules
or attachments thereto, of the Transmission Provided as amended from
time to time, and approved by FERC.
Preference: As defined in Central Valley Project's 2025 Marketing
Plan, is the requirements of Reclamation Law that provide for
preference in the sale of Federal power be given to certain entities,
such as governments (state, Federal and Native American),
municipalities and other public corporations or agencies, and
cooperatives and other nonprofit organizations financed in whole or in
part by loans made pursuant to the Rural Electrification Act of 1936
(See, e.g., Reclamation Project Act of 1939, Section 9(c), 43 U.S.C.
485h(c)).
Point-to-Point Transmission Service: As defined in WAPA's OATT, is
the reservation and transmission of capacity and energy on either a
firm or non-firm basis from the Point(s) of Receipt to the Point(s) of
Delivery under Part II of the Tariff.
Project Use: As defined in Central Valley Project's 2025 Marketing
Plan, is power as defined by Reclamation Law and/or used to operate CVP
and Washoe Project facilities.
Power: Capacity and energy.
Provisional Formula Rates: The formula rates confirmed, approved,
and placed into effect on an interim basis by the Deputy Secretary of
Energy or designee.
PRR: Power Revenue Requirement is revenue required by the PRS to
recover annual expenses (such as operation and maintenance, purchase
power, transmission service expenses, interest, and deferred expenses)
and repay Federal investments and other assigned costs.
PRS: Power Repayment Study, is defined in 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

[[Page 59085]]

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.
Rate: As defined in WAPA's OATT, means the monetary charge or the
formula for computing such a charge for any electric service provided
by a Transmission Provider as defined in 10 CFR part 903.
Rate Adjustment: Rate Adjustment means a change in an existing rate
or rates, or the establishment of a rate or rates for a new service. It
does not include a change in rate schedule provisions or in contract
terms, other than changes in the price per unit of service, nor does it
include changes in the monetary charge pursuant to a formula stated in
a rate schedule or a contract as defined in 10 CFR part 903.
Regulation: As defined in CAISO's Tariff, is the service provided
either by resources certified by the CAISO as equipped and capable of
responding to the CAISO's direct digital control signals, or by System
Resources that have been certified by the CAISO as capable of
delivering such service to the CAISO BAA, in an upward and downward
direction to match, on a real-time basis, demand and resources,
consistent with established NERC and Western Electricity Coordinating
Council (WECC) reliability standards and any requirements of the
Nuclear Regulatory Commission, or its successor. Regulation is used to
control the operating level of a resource within a prescribed area in
response to a change in system frequency, tie line loading, or the
relation of these to each other so as to maintain the target system
frequency and/or the established Interchange with other BAAs within the
predetermined Regulation Limits. Regulation includes both an increase
in energy production by a resource or decrease in energy consumption by
a resource (Regulation Up) and a decrease in energy production by a
resource or increase in energy consumption by a resource (Regulation
Down). Regulation Up and Regulation Down are distinct capacity
products, with separately stated requirements and Ancillary Service
Marginal Pricings in each Settlement Period.
Resource Sufficiency: CAISO defines and proposes resource
sufficiency evaluation that require all BAAs offer sufficient resources
to meet their bid-in demand, reliability capacity to meet forecasted
net load, provide ramp capability to meet their 24-hour net demand
variation, and their forecasted ancillary service and imbalance reserve
requirements (adjusted for diversity benefit).
Short-Term Firm Point-to-Point Transmission Service: As defined in
WAPA's OATT, is Firm Point-to-Point Transmission Service under Part II
of the Tariff with a term of less than one year.
Sub-BAA: As defined in WAPA's OATT, is Sub-Balancing Authority
Area. An electric power system operating within a host BAA that is
bounded by meters and is responsible for BAA-like performance of
generation, load, and transmission. WAPA-SN is a Sub-BAA within the
BANC BAA.
Tariff: As defined in WAPA's OATT, is the Open Access Transmission
Tariff, including all schedules or attachments thereto, of the
Transmission Provided as amended from time to time, and approved by
FERC.
TO: As defined in WAPA's OATT, means Transmission Owner and is the
entity that owns, leases or otherwise possesses an interest in the
portion of the Transmission System at the Point of Interconnection and
may be a Party to the Small Generator Interconnection Agreement to the
extent necessary.
Transmission Customer: As defined in WAPA's OATT, is any Eligible
Customer (or its Designated Agent) that (i) executes a Service
Agreement, or (ii) requests in writing that the Transmission Provider
provide transmission service without a Service Agreement, pursuant to
section 15.3 of the Tariff. This term is used in the Part I Common
Service Provisions to include customers receiving transmission service
under PartII and Part III of this Tariff.
Transmission Customer Base Schedule: As defined in WAPA's OATT,
Attachment S, is an energy schedule that provides Transmission Customer
hourly-level forecast data and other information used as the baseline
by which to measure Imbalance Energy for purposes of EIM settlement.
The term ``Transmission Customer Base Schedule'' as used in this Tariff
is synonymous with the term ``EIM Participant Base Schedule'' used in
the EIM Entity's business practices and may refer collectively to the
components of such schedule (resource, Interchange, Intrachange, and
load determined pursuant to the EIM Entity's business practices) or any
individual components of such schedule. This term is synonymous to
``Base Schedule.''
Transmission Provider: As defined in WAPA's OATT, is the regional
office within WAPA-SN that owns, controls, or operates the facilities
used for the transmission of electric energy in interstate commerce and
provides transmission service under the Tariff.
Transmission System: As defined in WAPA's OATT, is the facilities
owned, controlled, or operated by the Transmission Provider that are
used to provide transmission service under Part II and Part III of the
Tariff.
UIE: As defined in WAPA's OATT, Attachment S, is Uninstructed
Imbalance Energy. Settlement charges incurred by the Transmission
Provider on behalf of Transmission Customers due to uninstructed
deviations of supply or demand.
WECC: The Western Electricity Coordinating Council.

Effective Date

The Provisional Formula Rate Schedules CV-F14, CPP-3, CV-T4, CV-
NWT6, COTP-T4, CV-TPT8, CV-UUP2, CV-SPR5, CV-SUR5, CV-RFS5, CV-EID6,
CV-GID3, CV-SSP3, CV-EIM1S1, CV-EIM4S1, and CV-EIM9S1 will take effect
on the first day of the first full billing period beginning on or after
October 1, 2024, and will remain in effect through September 30, 2029,
pending approval by FERC on a final basis or until superseded.

Public Notice and Comment

WAPA-SN followed the Procedures for Public Participation in Power
and Transmission Rate Adjustments and Extensions, 10 CFR part 903, in
developing these formula rates. WAPA-SN took the following steps to
involve interested parties in the rate process:
1. On August 30, 2023, a Federal Register notice (88 FR 59909)
(Proposed FRN) announced the proposed formula rates and initiated a 90-
day public consultation and comment period.
2. On August 31, 2023, WAPA-SN notified Preference Customers and
interested parties of the proposed rates and provided a copy of the
Proposed FRN.
3. On November 15, 2023, WAPA-SN held a public information forum
via Microsoft Teams. WAPA-SN's representatives explained the proposed
formula rates, answered questions, and gave notice that more
information was available in the Customer Rate Brochure.
4. On November 15, 2023, WAPA-SN held a public comment forum via
Microsoft Teams to provide an opportunity for customers and other
interested parties to comment for the record.
5. SN established a public website to post information about the
rate process. The website is located at: <a href="http://www.wapa.gov/about-wapa/regions/sn/sn-rates">www.wapa.gov/about-wapa/regions/sn/sn-rates</a>.

[[Page 59086]]

6. On November 17, 2023, a Federal Register notice (88 FR 80293)
announced that WAPA-SN extended the public comment period for an
additional 30-days, through December 28, 2023.
7. During the 120-day consultation and comment period, WAPA-SN
received three oral comment submissions and no written comment letters.
The comments and WAPA-SN'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 Organization

Northern California Power Agency, California.

Power Revenue Requirement and Allocation to Preference Customers

Before the start of each FY, WAPA-SN will continue to calculate and
publish an annual Power Revenue Requirement (PRR) to determine the
total cost of power. The total cost of power is allocated to WAPA-SN's
preference customers, namely, First Preference (FP) customers based on
their FP percentages, and the remaining amount to Base Resource (BR)
customers based on their BR allocation, adjusted for programs, such as
hourly exchange. The Trinity River Division Act of 1955 (69 Stat. 719)
and the Flood Control Act of 1962 (76 Stat.1173, 1191-1192) accorded FP
to CVP power customers in Trinity, Tuolumne, and Calaveras counties. A
BR customer, under the 2004 and 2025 Marketing Plans, is an entity that
has executed a BR contract and is allocated a percentage of the BR.
WAPA-SN prepares a Power Repayment Study (PRS) each FY to determine
if revenue will be sufficient to repay, within the required periods,
all costs assigned to the commercial power function. Project repayment
is measured over the long term to ensure repayment is met and to
maintain rate stability. The PRR is an estimate of revenues and
expenses including investment and repayment projections from the PRS.
Any variance from estimate to actual will increase or decrease annual
project repayment. Generally, the PRR includes Operation and
Maintenance (O & M) expenses, purchased power for Project Use and FP
customers' loads, interest, and other expenses (including any other
statutorily required costs or charges), investment repayment, and the
Washoe Project transfer. Revenues from Project Use, transmission,
ancillary services, and other services offset expenses in the PRR; and
the remainder is collected from BR and FP customers. The PRR is
reviewed during March of each year; and if such review results in a
change of $5 million or more to the annual PRR, collections are
adjusted over the remaining 6-month period.
For WAPA-SN to meet the load requirements beyond delivered BR for
Full Load Service (FLS) customers and Variable Resource (VR) customers,
WAPA-SN may make Supplemental Power (SP) purchases pursuant to the
Custom Product Power (CPP) rate schedule. FLS and VR customers who
contract with WAPA-SN for such service will pay all SP costs. FLS
customers pay a portfolio management charge according to their
contract, whereas VR customers pay a scheduling charge per the rate
schedule.

Transmission and Ancillary Services Revenue Requirements and Formula
Rates

At least annually, WAPA-SN will apply the formula rates to
calculate and then post the CVP transmission rates for point-to-point
and Network Integration Transmission Service (NITS), the California
Oregon Transmission Project (COTP) transmission rates, and CVP
regulation and frequency response service rates. WAPA-SN prepares a
detailed cost-of-service study to determine the costs, by project, that
support the transfer capability of each transmission system and the
cost that supports the generation capability of the CVP system.
Generally, the costs allocated through the cost-of-service study for
the transmission systems include O & M, interest, and depreciation
expenses. WAPA-SN's costs for scheduling, system control and dispatch
service associated with CVP and COTP transmission service are included
and recovered through the respective transmission system's revenue
requirement. Third-party transmission service costs are passed through
directly to each requesting customer.
The unreserved use penalties continue to be assessed at 200percent
of the effective point-to-point transmission rate when transmission
service is used and not reserved, or when used in excess of the
reservation. The required spinning and supplemental reserves charges
are based on a price consistent with the California Independent System
Operator's (CAISO) market price plus all costs incurred for the sale of
these reserves. Customers who have a contractual obligation to provide
spinning and supplemental reserves and do not fulfill their obligation
will be assessed a penalty equal to the greater of WAPA-SN's actual
cost or 150percent of the market price.
For Energy Imbalance (EI) service, when the EIM is suspended,
customers outside of their contractual bandwidth (under delivery) will
pay the greater of 150percent of the market price or WAPA-SN's actual
cost. Given WAPA-SN's EI customers are and will continue to operate
under existing agreements, WAPA-SN will continue its existing rate
methodology for EI. The GI rate uses the same tiered methodology as
WAPA-SN's EI service rate.

Sale of Surplus Products Formula Rates

The provisional rates are for the sale of surplus energy and/or
capacity products. This includes Energy, Frequency Response Reserve,
Regulation, Reserves, and Resource Sufficiency. If CVP surplus products
are available, WAPA-SN will make the product(s) available for sale,
provided entities enter into separate agreement(s) which would specify
the terms of sale(s).

EIM Service Formula Rates

WAPA-SN will continue participation in the EIM as a Transmission
Service Provider and Participating Resource Scheduling Coordinator
within the Balancing Authority of Northern California (BANC) Balancing
Authority Area (BAA). WAPA-SN is continuing formula rate schedules for:
(1) EIM Administrative Service, (2) EIM EI Service, and (3) EIM GI
Service. In EIM, CAISO economically dispatches energy under its EIM
Tariff to meet the imbalances for loads and resources over multiple
BAAs. CAISO provides a centralized, automated, and region-wide dispatch
for imbalances. The EIM Administrative Services formula rate continues
to allow WAPA-SN to pass through administrative costs incurred by WAPA-
SN resulting from its participation in EIM as a Participating Resource
Scheduling Coordinator. The formula rates and cost allocation for
Administrative, EI, and GI services will be in effect when WAPA-SN is
participating in the EIM, and to the extent WAPA-SN incurs associated
settlements during market suspension or contingency.

Comments

WAPA-SN received three separate oral 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.
Comment: Commenter questioned the reasoning behind changing the
COTP rate period from three seasonal rates to

[[Page 59087]]

one annual rate. Commenter inquired if there was variation between
seasons.
Response: The reasoning for the seasonal change to one annual
period is that there is very little change between the seasonal rates.
Comment: Commenter questioned whether there has been any recent
change to the percentage losses that are charged on the COTP?
Response: While transmission loss factors are outside the scope of
the rate process, there have been no recent changes to the percentage
loss factors.
Comment: Commentor stated that WAPA-SN has an agreement with
Pacific Gas and Electric (PG & E) for distribution through their
transmission lines through 2024. They asked if there is any reason to
expect issues with the renewal, and to elaborate on the implications
for WAPA-SN customers if this contract with PG & E is not renewed.
Response: While transmission distribution agreements are outside
the scope of the rate process, WAPA-SN does have an existing agreement
with PG & E through 2024 and is in negotiations for an extension or a
renegotiation of those arrangements.

Certification of Rates

I have certified that the Provisional Formula Rates for Central
Valley Project power, transmission, and ancillary services; and
California-Oregon Transmission Project transmission service under Rate
Schedules CV-F14, CPP-3, CV-T4, CV-NWT6, COTP-T4, CV-TPT8, CV-UUP2, CV-
SPR5, CV-SUR5, CV-RFS5, CV-EID6, CV-GID3, CV-SSP3, CV-EIM1S1, CV-
EIM4S1, and CV-EIM9S1, 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 WAPA-SN to develop the Provisional Formula
Rates is available for inspection and copying at the WAPA-SN Regional
Office, 114 Parkshore Drive, Folsom, California. Many of these
documents are also available on WAPA-SN's website at <a href="http://www.wapa.gov/about-wapa/regions/sn/sn-rates">www.wapa.gov/about-wapa/regions/sn/sn-rates</a>.

Ratemaking Procedure Requirements

Environmental Compliance

WAPA-SN has determined that this action fits within the following
categorical exclusion listed in appendix B to subpart D of 10 CFR part
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.\3\ A
copy of the categorical exclusion determination is available on WAPA's
website at: <a href="http://www.wapa.gov/about-wapa/regions/sn/environment">www.wapa.gov/about-wapa/regions/sn/environment</a>.
---------------------------------------------------------------------------

\3\ 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-SN 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-207. 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 15,
2024, 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 17, 2024.
Treena V. Garrett,
Federal Register Liaison Officer, U.S. Department of Energy.

Rate Schedule CV-F14
(Supersedes Schedule CV-F13)

UNITED STATES DEPARTMENT OF ENERGY

Western Area Power Administration

Central Valley Project

Base Resource and First Preference Power

(Approved Under Rate Order No. WAPA-207)

Effective

October 1, 2024, through September 30, 2029, or until superseded,
whichever occurs earlier.

Available

In the area served by the Western Area Power Administration (WAPA),
Sierra Nevada Region (SN).

Applicable

To the Base Resource (BR) and First Preference (FP) Power
Customers.

Character and Conditions of Service

Alternating current, 60-hertz, three-phase, delivered and metered
at the voltages and points established by contract. This service
includes the Central Valley Project (CVP) transmission (to include
reactive supply and voltage control from Federal generation sources
needed to support the transmission service), spinning reserve service,
and supplemental reserve service.

Formula Rate

The formula rate includes three components.
Component 1
Power Revenue Requirement (PRR):
WAPA-SN will develop the PRR before the start of each fiscal year
(FY). The PRR will be divided into two 6-month periods, October through
March, and April through September, based on FP and BR percentages. The
PRR will be reviewed in March of each year. If there is a change of $5
million or more, the PRR will be recalculated for the entire FY. The
PRR is allocated to FP Customers and BR Customers based on formula
rates, as adjusted for Hourly Exchange (HE), FP true-up calculation and
midyear adjustments.
FP Power Formula Rate:
The annual FP customer allocation is equal to the annual PRR
multiplied by the relevant FP percentage.

[[Page 59088]]

[GRAPHIC] [TIFF OMITTED] TN22JY24.202

Where:

FP Customer Load = FP Customer's forecasted annual load (MWh)
Gen = Forecasted annual CVP and Washoe generation (MWh)
Power Purchases = Power purchases for Project Use and FP loads (MWh)
Project Use = Forecasted annual Project Use loads (MWh)

WAPA-SN will develop each FP customer's percentage before the start
of each FY, and review in March every year. If there is a change of
more than one-half of 1 percent, the percentage will be revised for the
full FY and billing will be adjusted over the remaining 6 months.
In addition, WAPA-SN will perform a true-up each year to ensure FP
Customers pay their proportionate share of the PRR. The FP customers'
percentage is limited to a percentage of the PRR. The table below shows
the maximum percentages for each FP customer that will be applied to
the PRR. FP percentages cannot exceed the maximum except in instances
where a FP customers' percentage increases due to load growth. If
maximum percentages are exceeded for more than one year, WAPA-SN will
reevaluate and update customer maximum percentages.

FP Maximum Percentages
------------------------------------------------------------------------
Maximum FP
customer
FP customer percentage
applied to the
PRR
------------------------------------------------------------------------
Sierra Conservation Center.............................. 1.58
Calaveras Public Power Agency........................... 3.81
Trinity Public Utilities District....................... 12.01
Tuolumne Public Power Agency............................ 3.16
Chicken Ranch Rancheria................................. 0.96
---------------
Total................................................. 21.52
------------------------------------------------------------------------

BR Formula Rate:
The annual BR customer allocation is equal to the annual PRR
multiplied by the relevant BR percentage.

BR Customer Allocation = (PRR x BR%)

Where:

BR% = BR percentage for each customer as indicated in the BR
contract after adjustments for programs, such as HE, if applicable

After the FP Customers' share of the annual PRR has been
determined, including a prior period true-up from the FP formula rate,
the remainder of the annual PRR is recovered from the BR Customers. The
BR Revenue Requirement will be collected in two 6-month periods: 25%
for October through March and 75% for April through September.
Component 2
Any charges or credits associated with the creation, termination,
or modification to any tariff, contract, or rate schedule accepted or
approved by FERC or other regulatory body will be passed on to each
relevant customer. The charges or credits apply to the service to which
this rate methodology applies. When possible, WAPA-SN will pass through
charges or credits directly to the customer in the same manner WAPA-SN
is charged or credited. When not possible, the charges or credits will
be passed through using Component 1 of the formula rate.
Component 3
Any charges or credits from the Host Balancing Authority for
providing this service will be passed on to each relevant customer.
When possible, WAPA-SN will pass through charges and credits directly
to the customer in the same manner WAPA-SN is charged or credited. When
not possible, the charges or credits will be passed through using
Component 1 of the formula rate.

Billing

Billing for BR and FP power will occur monthly using the respective
formula rate. Any adjustment made at midyear applies to the entire FY
and is billed over the remainder of the FY.

Adjustment for Losses

Losses will be accounted for under this rate schedule as stated in
the service agreement.

Audit Adjustments

Financial audit adjustments that apply to the formula rate under
this rate schedule will be evaluated on a case-by-case basis to
determine the appropriate treatment for repayment and cash flow
management.

Rate Schedule CPP-3
(Supersedes Schedule CPP-2)

UNITED STATES DEPARTMENT OF ENERGY

Western Area Power Administration

Central Valley Project

Custom Product Power

Effective

October 1, 2024, through September 30, 2029, or until superseded,
whichever occurs earlier.

Available

In the area served by the Western Area Power Administration (WAPA),
Sierra Nevada Region (SN).

Applicable

To Sierra Nevada Region (SN) customers that contract for Custom
Product Power (CPP). CPP means capacity and energy, provided by WAPA-
SN, in addition to a customer's Base Resource, to meet its load.
To WAPA-SN Variable Resources (VR) Customers requesting scheduling
for this service. A scheduling charge is applicable to VR customers
requesting WAPA-SN to schedule CPP purchases.

Character and Conditions of Service

Alternating current, 60-hertz, three-phase, delivered and metered
at the voltages and points established by contract, in accordance with
approved policies and procedures.

Formula Rate

The formula rate includes three components.
Component 1
All charges and credits incurred in providing CPP will be passed
through to the customer. WAPA-SN will assess a VR scheduling charge per
schedule per day to cover the administrative costs for procuring and
scheduling CPP.

[[Page 59089]]

[GRAPHIC] [TIFF OMITTED] TN22JY24.216

If the actual number of schedules for the month is not available,
WAPA-SN will estimate the number of schedules for the month and apply
the VR scheduling charge to the estimated number of schedules.
Component 2
Any charges or credits associated with the creation, termination,
or modification to any tariff, contract, or rate schedule accepted or
approved by FERC or other regulatory body will be passed on to each
relevant customer. The charges or credits apply to the service to which
this rate methodology applies. When possible, WAPA-SN will pass through
charges or credits directly to the customer in the same manner WAPA-SN
is charged or credited. When not possible, the charges or credits will
be passed through using Component 1 of the formula rate.
Component 3
Any charges or credits from the Host Balancing Authority for
providing this service will be passed on to each relevant customer.
When possible, WAPA-SN will pass through charges and credits directly
to the customer in the same manner WAPA-SN is charged or credited. When
not possible, the charges or credits will be passed through using
Component 1 of the formula rate.

Billing

Billing for CPP and VR scheduling charge occurs monthly.

Adjustments for Losses

All losses incurred for the delivery of CPP under this rate
schedule shall be the responsibility of the customer that has
contracted for this service.

Audit Adjustments

Rate Schedule CV-T4
(Supersedes Schedules CV-T3)

UNITED STATES DEPARTMENT OF ENERGY

Western Area Power Administration

Central Valley Project

Point-To-Point Transmission Service

Effective

October 1, 2024, through September 30, 2029, or until superseded,
whichever occurs earlier.

Available

In the area served by the Western Area Power Administration (WAPA),
Sierra Nevada Region (SN).

Applicable

To customers receiving Central Valley Project (CVP) firm and/or
non-firm Point-to-Point (PTP) transmission service.

Character and Conditions of Service

Transmission service for three-phase, alternating current at 60
hertz, delivered and metered at the voltages and points of delivery or
receipt, adjusted for losses, and delivered to points of delivery. This
service includes scheduling and system control and dispatch service
needed to support the transmission service.

Formula Rate

The formula rate for CVP firm and non-firm PTP transmission
includes three components.
Component 1
CVP Transmission Revenue Requirement (TRR) = Contracted PTP
Transmission Capacity (PTPc) + Network Integration Transmission Service
Capacity (NITSc)

Where:

CVP TRR = the cost associated with facilities that support the
transfer capability of the CVP transmission system, excluding
generation facilities and radial lines
PTPc = the total PTP transmission capacity (kW) under long-term
contract between WAPA-SN and other parties
NITSc = the 12-month average coincident peaks (kW) of Network
Integrated Transmission Service (NITS) customers at the time of the
monthly CVP transmission system peak (kW)

WAPA-SN may revise the rate from Component 1 based on either of the
following conditions: (1) updated financial data available in March of
each year; or (2) a change in the numerator or denominator that results
in a rate change of at least $0.05 per kilowatt month (kW month). Rate
change notifications will be posted on WAPA-SN's Open Access Same-Time
Information System (OASIS) website.
Component 2
Any charges or credits associated with the creation, termination,
or modification to any tariff, contract, or rate schedule accepted or
approved by FERC or other regulatory body will be passed on to each
relevant customer. The charges or credits apply to the service to which
this rate methodology applies. When possible, WAPA-SN will pass through
charges or credits directly to the customer in the same manner WAPA-SN
is charged or credited. When not possible, the charges or credits will
be passed through using Component 1 of the formula rate.
Component 3
Any charges or credits from the Host Balancing Authority for
providing this service will be passed on to each relevant customer.
When possible, WAPA-SN will pass through charges and credits directly
to the customer in the same manner WAPA-SN is charged or credited. When
not possible, the charges or credits will be passed through using
Component 1 of the formula rate.

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 agreements.

Audit Adjustments

Rate Schedule CV-NWT6
(Supersedes Schedule CV-NWT5)

[[Page 59090]]

UNITED STATES DEPARTMENT OF ENERGY

Western Area Power Administration

Central Valley Project

Network Integration Transmission Service

Effective

October 1, 2024, through September 30, 2029, or until superseded,
whichever occurs earlier.

Available

In the area served by the Western Area Power Administration (WAPA),
Sierra Nevada Region (SN).

Applicable

To customers receiving Central Valley Project (CVP) Network
Integration Transmission Service (NITS).

Character and Conditions of Service

Formula Rate

The formula rate for CVP NITS includes three components:
Component 1
The NITS revenue requirement equals the CVP Transmission Revenue
Requirement (TRR) less the CVP firm point-to-point revenue. Each NITS
customer's allocation is based on the following formula:
[GRAPHIC] [TIFF OMITTED] TN22JY24.203

Where:

NITS customer's load ratio share = The NITS customer's load, hourly,
or in accordance with approved policies or procedures, (including
behind the meter generation minus the NITS customer's adjusted Base
Resource) coincident with the monthly CVP transmission system peak,
averaged over a 12-month rolling period, expressed as a ratio.
Annual Network TRR = The total CVP TRR less revenue from long-term
contracts for the CVP transmission between WAPA-SN and other
parties.

The Annual Network TRR will be revised when the formula rate from
Component 1 of the CVP transmission rate under Rates Schedule CV-T4 is
revised.
Component 2
Any charges or credits associated with the creation, termination,
or modification to any tariff, contract, or rate schedule accepted or
approved by FERC or other regulatory body will be passed on to each
relevant customer. The charges or credits apply to the service to which
this rate methodology applies. When possible, WAPA-SN will pass through
charges or credits directly to the customer in the same manner WAPA-SN
is charged or credited. When not possible, the charges or credits will
be passed through using Component 1 of the formula rate.
Component 3
Any charges or credits from the Host Balancing Authority for
providing this service will be passed on to each relevant customer.
When possible, WAPA-SN will pass through charges and credits directly
to the customer in the same manner WAPA-SN is charged or credited. When
not possible, the charges or credits will be passed through using
Component 1 of the formula rate.

Billing

NITS will be billed monthly under the formula rate.

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.

Audit Adjustments

Rate Schedule COTP-T4
(Supersedes Schedule COTP-T3)

UNITED STATES DEPARTMENT OF ENERGY

Western Area Power Administration

California-Oregon Transmission Project

Point-To-Point Transmission Service

Effective

October 1, 2024, through September 30, 2029, or until superseded,
whichever occurs earlier.

Available

In the area served by the Western Area Power Administration (WAPA),
Sierra Nevada Region (SN).

Applicable

To customers receiving California-Oregon Transmission Project
(COTP) firm and/or non-firm point-to-point (PTP) transmission service.

Character and Conditions of Service

Formula Rate

The formula rate for COTP firm and non-firm PTP transmission
service includes three components.
Component 1
[GRAPHIC] [TIFF OMITTED] TN22JY24.204

Where:

COTP Transmission Revenue Requirement (TRR) = WAPA-SN's costs
associated

[[Page 59091]]

with facilities that support the transfer capability of the COTP.
WAPA-SN's COTP Capacity = WAPA-SN's share of COTP transmission
capacity, subject to curtailment under the current California-Oregon
Intertie (COI) transfer capability.

WAPA-SN will update the rate from Component 1 at least 15 days
before the start of the rate period. Rate change notifications will be
posted on WAPA-SN's Open Access Same-Time Information System (OASIS)
website.
Component 2
Any charges or credits associated with the creation, termination,
or modification to any tariff, contract, or rate schedule accepted or
approved by FERC or other regulatory body will be passed on to each
relevant customer. The charges or credits apply to the service to which
this rate methodology applies. When possible, WAPA-SN will pass through
charges or credits directly to the customer in the same manner WAPA-SN
is charged or credited. When not possible, the charges or credits will
be passed through using Component 1 of the formula rate.
Component 3
Any charges or credits from the Host Balancing Authority for
providing this service will be passed on to each relevant customer.
When possible, WAPA-SN will pass through charges and credits directly
to the customer in the same manner WAPA-SN is charged or credited. When
not possible, the charges or credits will be passed through using
Component 1 of the formula rate.

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.

Audit Adjustments

Rate Schedule CV-TPT8
(Supersedes Schedule CV-TPT7)

UNITED STATES DEPARTMENT OF ENERGY

Western Area Power Administration

Central Valley Project

Transmission of WAPA-SN Power By Others

Effective

October 1, 2024, through September 30, 2029, or until superseded,
whichever occurs earlier.

Available

In the area served by the Western Area Power Administration (WAPA),
Sierra Nevada Region (SN).

Applicable

To WAPA-SN's power service customers who require transmission
service by a third-party to receive power sold by WAPA-SN.

Character and Conditions of Service

Formula Rate

The formula rate for transmission of WAPA-SN's power by others
includes three components.
Component 1
When WAPA-SN uses transmission facilities other than its own in
supplying WAPA-SN power and costs are incurred by WAPA-SN for the use
of such facilities, the customer will pay all costs, including
transmission losses, incurred in the delivery of such power.
Component 2
Any charges or credits associated with the creation, termination,
or modification to any tariff, contract, or rate schedule accepted or
approved by FERC or other regulatory body will be passed on to each
relevant customer. The charges or credits apply to the service to which
this rate methodology applies. When possible, WAPA-SN will pass through
charges or credits directly to the customer in the same manner WAPA-SN
is charged or credited. When not possible, the charges or credits will
be passed through using Component 1 of the formula rate.
Component 3
Any charges or credits from the Host Balancing Authority for
providing this service will be passed on to each relevant customer.
When possible, WAPA-SN will pass through charges and credits directly
to the customer in the same manner WAPA-SN is charged or credited. When
not possible, the charges or credits will be passed through using
Component 1 of the formula rate.

Billing

Third-party transmission will be billed monthly under the formula
rate.

Adjustments for Losses

All losses incurred for delivery of power under this rate schedule
will be the responsibility of the customer that received the power.

Audit Adjustments

Rate Schedule CV-UUP2
(Supersedes Rate Schedule CV-UUP1)

UNITED STATES DEPARTMENT OF ENERGY

Western Area Power Administration

Central Valley Project

Unreserved Use Penalties

Effective

October 1, 2024, through September 30, 2029, or until superseded,
whichever occurs earlier.

Available

In the area served by the Western Area Power Administration (WAPA),
Sierra Nevada Region (SN).

Applicable

To unreserved use of transmission service for the Central Valley
Project, California-Oregon Transmission Project, and Pacific
Alternating Current Intertie. This penalty is applicable to point-to-
point (PTP) transmission customers using transmission not reserved or
more than reserved, or network customers when they schedule delivery of
off-system non-designated purchases using transmission capacity
reserved for designated network resources.

Character and Conditions of Service

[[Page 59092]]

Penalty Rate

The formula rate for Unreserved Use Penalty (UUP) has three
components.
Component 1
A transmission customer that has not reserved capacity or exceeds
its firm or non-firm reserved capacity at any point of receipt or any
point of delivery will be assessed UUP.
The penalty charge for a transmission customer who engages in
unreserved use is 200 percent of WAPA-SN's approved transmission
service rate for PTP transmission service assessed as follows: (1) the
UUP for a single hour of unreserved use will be based upon the rate for
daily firm PTP service; (2) the UUP for more than one assessment for a
given duration (e.g., daily) will increase to the next longest duration
(e.g., weekly); and (3) the UUP for multiple instances of unreserved
use (e.g., more than 1 hour) within a day will be based on the rate for
daily firm PTP service. The penalty charge for multiple instances of
unreserved use isolated to one-calendar week would result in a penalty
based on the charge for weekly firm PTP service. The penalty charge for
multiple instances of unreserved use during more than one week within a
calendar month is based on the charge for monthly firm PTP service.
The UUP will not apply to transmission customers utilizing PTP
transmission service under WAPA's Open Access Transmission Tariff
(OATT) because of action taken to support reliability. Such actions
include reserve activations or uncontrolled event response as directed
by the responsible reliability authority such as Sub-Balancing
Authority, Host Balancing Authority (HBA), Reliability Coordinator, or
Transmission Operator.
A transmission customer that exceeds its firm or non-firm reserved
capacity is required to pay for all ancillary services identified in
WAPA's OATT associated with the unreserved use of transmission service.
The transmission customer or eligible customer will pay for ancillary
services, in accordance with existing rate schedules, based on the
amount of transmission service it used but did not reserve.
The UUP collected over and above the base PTP rate will be
distributed to customers as a credit on future transmission revenue
requirements.
Component 2
Any charges or credits associated with the creation, termination,
or modification to any tariff, contract, or rate schedule accepted or
approved by FERC or other regulatory body will be passed on to each
relevant customer. The charges or credits apply to the service to which
this rate methodology applies. When possible, WAPA-SN will pass through
charges or credits directly to the customer in the same manner WAPA-SN
is charged or credited. When not possible, the charges or credits will
be passed through using Component 1 of the formula rate.
Component 3
Any charges or credits from the HBA for providing this service will
be passed on to each relevant customer. When possible, WAPA-SN will
pass through charges and credits directly to the customer in the same
manner WAPA-SN is charged or credited. When not possible, the charges
or credits will be passed through using Component 1 of the formula
rate.

Billing

The UUP will be billed monthly under the formula rate.

Adjustment for Losses

Losses incurred for delivery of power under this rate schedule
shall be the responsibility of the customer that received the power.

Audit Adjustments

Financial audit adjustments that apply to the formula rate will be
evaluated on a case-by-case basis to determine the appropriate
treatment for repayment and cash flow management.
Rate Schedule CV-RFS5
(Supersedes Schedule CV-RFS4)

UNITED STATES DEPARTMENT OF ENERGY

Western Area Power Administration

Central Valley Project

Regulation and Frequency Response Service

Effective

October 1, 2024, through September 30, 2029, or until superseded,
whichever occurs earlier.

Available

In the area served by the Western Area Power Administration (WAPA),
Sierra Nevada Region (SN).

Applicable

To customers receiving Regulation and Frequency Response Service
(Regulation).

Character and Conditions of Service

Regulation is necessary to provide for the continuous balancing of
resources and interchange with load and for maintaining scheduled
interconnection frequency at 60 cycles per second. Regulation is
accomplished by committing on-line generation whose output is raised or
lowered, predominantly using automatic generating control equipment, as
necessary, to follow the moment-by-moment changes in load.

Formula Rate

The formula rate for regulation includes three components:
Component 1
[GRAPHIC] [TIFF OMITTED] TN22JY24.205

Where:

The annual regulation revenue requirement includes: (1) the Central
Valley Project generation costs associated with providing
regulation, and (2) the non-facility costs allocated to regulation;
and is calculated by dividing the Generation Revenue Requirement by
the prior year plant capacity usage times the Regulation capacity.
The annual regulating capacity is one-half of the total
regulating capacity bandwidths provided by WAPA-SN under the
Interconnected Operations Agreements with Sub-Balancing Authority
(SBA) members.
The penalty for non-performance by an SBA customer who has
committed to self-provision for their regulating capacity
requirement will be the greater of 150 percent of WAPA-SN's actual
costs or 150 percent of the market price.

WAPA-SN will revise the formula rate resulting from Component 1
based on either of the following two conditions: (1) updated financial
data available in March of each year; or (2) a change in the numerator
or denominator that results in a rate change of at least $0.25 per kW
month.
Component 2
Any charges or credits associated with the creation, termination,
or modification to any tariff, contract, or rate schedule accepted or
approved by

[[Page 59093]]

FERC or other regulatory body will be passed on to each relevant
customer. The charges or credits apply to the service to which this
rate methodology applies. When possible, WAPA-SN will pass through
charges or credits directly to the customer in the same manner WAPA-SN
is charged or credited. When not possible, the charges or credits will
be passed through using Component 1 of the formula rate.
Component 3
Any charges or credits from the Host Balancing Authority for
providing this service will be passed on to each relevant customer.
When possible, WAPA-SN will pass through charges and credits directly
to the customer in the same manner WAPA-SN is charged or credited. When
not possible, the charges or credits will be passed through using
Component 1 of the formula rate.

Billing

The formula rate above will be applied to the regulating capacity
bandwidth contained in the service agreement. Billing will occur
monthly.

Audit Adjustments

Rate Schedule CV-SPR5
(Supersedes Schedule CV-SPR4)

UNITED STATES DEPARTMENT OF ENERGY

Western Area Power Administration

Central Valley Project

Operating Reserve-Spinning Reserve Service

Effective

October 1, 2024, through September 30, 2029, or until superseded,
whichever occurs earlier.

Available

In the area served by the Western Area Power Administration (WAPA),
Sierra Nevada Region (SN).

Applicable

To customers receiving spinning reserve service.

Character and Conditions of Service

Spinning Reserve Service supplies capacity that is available
immediately to serve load and is synchronized with the power system.

Formula Rate

The formula rate for spinning reserve includes three components:
Component 1
The formula rate for spinning reserve service is the price
consistent with the California Independent System Operator's (CAISO)
market plus all costs incurred from the sale of spinning reserves, such
as WAPA-SN's scheduling costs.
For customers that have a contractual obligation to provide
spinning reserve to WAPA-SN and do not fulfill that obligation, the
penalty for non-performance is the greater of 150 percent of WAPA-SN's
actual cost or 150 percent of the market price.
Component 2
Any charges or credits associated with the creation, termination,
or modification to any tariff, contract, or rate schedule accepted or
approved by FERC or other regulatory body will be passed on to each
relevant customer. The charges or credits apply to the service to which
this rate methodology applies. When possible, WAPA-SN will pass through
charges or credits directly to the customer in the same manner WAPA-SN
is charged or credited. When not possible, the charges or credits will
be passed through using Component 1 of the formula.
Component 3
Any charges or credits from the Host Balancing Authority for
providing this service will be passed on to each relevant customer.
When possible, WAPA-SN will pass through charges and credits directly
to the customer in the same manner WAPA-SN is charged or credited. When
not possible, the charges or credits will be passed through using
Component 1 of the formula rate.

Billing

The formula rate above will be applied to the amount of spinning
reserve sold. Billing will occur monthly.

Audit Adjustments

Rate Schedule CV-SUR5
(Supersedes Schedule CV-SUR4)

UNITED STATES DEPARTMENT OF ENERGY

Western Area Power Administration

Central Valley Project

Operating Reserve-Supplemental Reserve Service

Effective

October 1, 2024, through September 30, 2029, or until superseded,
whichever occurs earlier.

Available

In the area served by the Western Area Power Administration (WAPA),
Sierra Nevada Region (SN).

Applicable

To customers receiving supplemental reserve service.

Character and Conditions of Service

Supplemental reserve service supplies capacity that is available
within the first 10 minutes to take load and is synchronized with the
power system.

Formula Rate

The formula rate for supplemental reserve service includes three
components:
Component 1
The formula rate for supplemental reserve service is the price
consistent with the California Independent System Operator's (CAISO)
market plus all costs incurred as a result of the sale of supplemental
reserves, such as WAPA-SN's scheduling costs.
For customers that have a contractual obligation to provide
supplemental reserve service to WAPA-SN and do not fulfill that
obligation, the penalty for non-performance is the greater of 150
percent of WAPA-SN's actual cost or 150 percent of the market price.
Component 2
Any charges or credits associated with the creation, termination,
or modification to any tariff, contract, or rate schedule accepted or
approved by FERC or other regulatory body will be passed on to each
relevant customer. The charges or credits apply to the service to which
this rate methodology applies. When possible, WAPA-SN will pass through
charges or credits directly to the customer in the same manner WAPA-SN
is charged or credited. When not possible, the charges or credits will
be passed through using Component 1 of the formula rate.
Component 3
Any charges or credits from the Host Balancing Authority for
providing this

[[Page 59094]]

service will be passed on to each relevant customer. When possible,
WAPA-SN will pass through charges and credits directly to the customer
in the same manner WAPA-SN is charged or credited. When not possible,
the charges or credits will be passed through using Component 1 of the
formula rate.

Billing

The formula rate above will be applied to the amount of
supplemental reserve service sold. Billing will occur monthly.

Audit Adjustments

UNITED STATES DEPARTMENT OF ENERGY

Western Area Power Administration

Central Valley Project

Energy Imbalance Service

Effective

October 1, 2024, through September 30, 2029, or until superseded,
whichever occurs earlier.

Available

In the area served by the Western Area Power Administration (WAPA),
Sierra Nevada Region (SN).

Applicable

To customers receiving Energy Imbalance (EI) Service.

Character and Conditions of Service

EI Service is provided when a difference occurs between the
scheduled and the actual delivery of energy to a load within the Sub-
Balancing Authority (SBA) over an hour or in accordance with approved
policies and procedures. The deviation, in megawatts, is the net
scheduled amount of energy minus the net metered (actual delivered)
amount.
EI Service uses the deviation bandwidth that is established in the
service agreement or Interconnected Operations Agreements.

Formula Rate

The formula rate for EI Service includes three components:
Component 1
EI Service charges are applied to deviations as follows unless
otherwise dictated by contract or policy: (1) deviations within the
bandwidth will be tracked and settled financially, at the greater of
the California Independent System Operator (CAISO) market price, or
WAPA-SN's actual cost; (2) negative deviations (under-delivery),
outside the deviation bandwidth, will be charged the greater of 150
percent of the CAISO market price or 150 percent of WAPA-SN's actual
cost; and (3) positive deviations (over-delivery), outside the
deviation bandwidth, will be lost to the system, except for any hour
when WAPA-SN incurs a cost to dispose of the energy, in which event the
responsible party will bear that cost.
Deviations that occur due to actions taken to support reliability
will be resolved in accordance with existing contractual requirements.
Such actions include reserve activations or uncontrolled event
responses as directed by the responsible reliability authority such as
SBA, Host Balancing Authority (HBA), Reliability Coordinator, or
Transmission Operator.
Component 2
Any charges or credits associated with the creation, termination,
or modification to any tariff, contract, or rate schedule accepted or
approved by FERC or other regulatory body will be passed on to each
relevant customer. The charges or credits apply to the service to which
this rate methodology applies. When possible, WAPA-SN will pass through
charges or credits directly to the customer in the same manner WAPA-SN
is charged or credited. When not possible, the charges or credits will
be passed through using Component 1 of the formula rate.
Component 3
Any charges or credits from the HBA for providing this service will
be passed on to each relevant customer. When possible, WAPA-SN will
pass through charges and credits directly to the customer in the same
manner WAPA-SN is charged or credited. When not possible, the charges
or credits will be passed through using Component 1 of the formula
rate.

Billing

Billing for negative deviations outside the bandwidth, or as
otherwise required, will occur monthly.

Audit Adjustments

Rate Schedule CV-GID3
(Supersedes Schedule CV-GID2)

UNITED STATES DEPARTMENT OF ENERGY

Western Area Power Administration

Central Valley Project

Generator Imbalance Service

Effective

October 1, 2024, through September 30, 2029, or until superseded,
whichever occurs earlier.

Available

In the area served by the Western Area Power Administration (WAPA),
Sierra Nevada Region (SN).

Applicable

To generators receiving Generator Imbalance (GI) Service.

Character and Conditions of Service

GI Service is provided when a difference occurs between the
scheduled and actual delivery of energy from an eligible generation
resource within the Sub-Balancing Authority (SBA), over an hour, or in
accordance with approved policies. The deviation in megawatts is the
net scheduled amount of generation minus the net metered output from
the generator's (actual generation) amount.
GI Service is subject to the deviation bandwidth established in the
service agreement or Interconnected Operations Agreements.

Formula Rate

The formula rate for the GI Service has three components:
Component 1
GI Service is applied to deviations as follows unless otherwise
dictated by contract or policy: (1) deviations within the bandwidth
will be tracked and settled financially at the greater of the
California Independent System Operator (CAISO) market price or WAPA-
SN's actual cost; (2) negative deviations (under-delivery), outside the
deviation bandwidth, will be charged the greater of 150 percent of the
CAISO market price or 150 percent of WAPA-SN's actual cost; and (3)
positive deviations (over-delivery), outside the deviation bandwidth,
will be lost to the system, except for any hour when WAPA-SN incurs a
cost to dispose of the energy, in which event the responsible party
will bear that cost.
Deviations that occur due to actions taken to support reliability
will be resolved in accordance with existing contractual requirements.
Such actions include reserve activations or

[[Page 59095]]

uncontrolled event responses as directed by the responsible reliability
authority such as SBA, Host Balancing Authority (HBA), Reliability
Coordinator, or Transmission Operator.
To the extent that an entity incorporates intermittent resources,
deviations will be charged as follows unless otherwise dictated by
contract or policy: (1) deviations within the bandwidth will be tracked
and settled financially at the greater of the CAISO market price or
WAPA-SN's actual cost; (2) negative deviations (under-delivery),
outside the deviation bandwidth, will be charged the greater of market
price or actual cost (no penalty); and (3) positive deviations (over-
delivery), outside the deviation bandwidth, will be lost to the system,
except for any hour where WAPA-SN incurs a cost, then that cost will be
borne by the responsible party.
Intermittent generators serving load outside of WAPA-SN's SBA will
be required to dynamically schedule or dynamically meter their
generation to another Balancing Authority. An intermittent resource,
for the limited purpose of these rate schedules, is an electric
generator that is not dispatchable and cannot store its output, and
therefore, cannot respond to changes in demand or respond to
transmission security constraints.
Component 2
Any charges or credits associated with the creation, termination,
or modification to any tariff, contract, or rate schedule accepted or
approved by FERC or other regulatory body will be passed on to each
relevant customer. The charges or credits apply to the service to which
this rate methodology applies. When possible, WAPA-SN will pass through
charges or credits directly to the customer in the same manner WAPA-SN
is charged or credited. When not possible, the charges or credits will
be passed through using Component 1 of the formula rate.
Component 3
Any charges or credits from the HBA for providing this service will
be passed on to each relevant customer. When possible, WAPA-SN will
pass through charges and credits directly to the customer in the same
manner WAPA-SN is charged or credited. When not possible, the charges
or credits will be passed through using Component 1 of the formula
rate.

Billing

Billing for negative deviations outside the bandwidth will occur
monthly.

Audit Adjustments

Rate Schedule CV-SSP3
(Supersedes Schedule CV-SSP2)

UNITED STATES DEPARTMENT OF ENERGY

Western Area Power Administration

Central Valley Project

Sale of Surplus Products

Effective

October 1, 2024, through September 30, 2029, or until superseded by
another rate schedule, whichever occurs earlier.

Available

In the area served by the Western Area Power Administration (WAPA),
Sierra Nevada Region (SN).

Applicable

To WAPA-SN customers participating in the Sale of Surplus Products.

Character and Conditions of Service

Sale of Surplus Products occurs when there is a sale of surplus
energy and/or capacity products. This includes: (1) Energy, (2)
Frequency Response Service, (3) Regulation, (4) Reserves, and (5)
Resource Sufficiency. If any of the surplus products are available,
WAPA-SN could make the product(s) available for sale, provided entities
enter into separate agreement(s) which will specify the terms of
sale(s).

Formula Rate

The formula rate for Sale of Surplus Products service includes
three components:
Component 1
WAPA-SN will determine the charge for each product at the time of
sale to be the greater of WAPA-SN's cost or market rates, to include
transmission charges. WAPA-SN will use a separate agreement(s) to
specify the terms of sale(s). The customer may be responsible for
acquiring additional transmission service necessary to deliver the
product(s), for which a separate charge may be incurred from the
transmission provider.
Component 2
Any charges or credits associated with the creation, termination,
or modification to any tariff, contract, or rate schedule accepted or
approved by FERC or other regulatory body will be passed on to each
relevant customer. The charges or credits apply to the service to which
this rate methodology applies. When possible, WAPA-SN will pass through
charges or credits directly to the customer in the same manner WAPA-SN
is charged or credited. When not possible, the charges or credits will
be passed through using Component 1 of the formula rate.
Component 3
Any charges or credits from the Host Balancing Authority for
providing this service will be passed on to each relevant customer.
When possible, WAPA-SN will pass through charges and credits directly
to the customer in the same manner WAPA-SN is charged or credited. When
not possible, the charges or credits will be passed through using
Component 1 of the formula rate.

Billing

The formula rate above will be applied to the Sale of Surplus
product(s) sold. Billing will occur monthly.

Audit Adjustments

Rate Schedule CV-EIM1S1
(Supersedes Rate Schedule CV-EIM1S)

UNITED STATES DEPARTMENT OF ENERGY

Western Area Power Administration

Central Valley Project

Energy Imbalance Market

Administrative Service

Effective

October 1, 2024, through September 30, 2029, or until superseded,
whichever occurs earlier.

Available

In the area served by the Western Area Power Administration (WAPA),
Sierra Nevada Region (SN).

Applicable

This rate applies to WAPA-SN customers when WAPA-SN, as the
Transmission Provider, is participating in Energy Imbalance Market
(EIM) and when the EIM has not been suspended. To the extent WAPA-SN
incurs EIM Administrative Service-related costs from the EIM Entity
during periods of market suspension or contingency, this schedule will
also apply to ensure that

[[Page 59096]]

WAPA-SN, as Transmission Provider, remains revenue neutral for its
participation in EIM.

Character and Conditions of Service

The EIM Administrative Service rate recovers the administrative
costs for participating in the EIM by WAPA-SN as a Transmission
Provider, including but not limited to such administrative charges as
may be incurred by WAPA-SN from California Independent System Operator
(CAISO) as the EIM Market Operator (MO) and/or Balancing Authority of
Northern California (BANC) as the EIM Entity.
Unless such charges are allocated to the Transmission Customer
directly by BANC, all Transmission Customers purchasing Long-Term Firm
Point-to-Point Transmission Service, Short-Term Firm Point-to-Point
Transmission Service, Non-Firm Point-to-Point Transmission Service, or
Network Integration Transmission Service from WAPA-SN shall incur an
EIM Administrative Service Charge from WAPA-SN.
CAISO's Administrative Service Charge, as defined in the MO Tariff,
is included in this rate. This rate also includes administrative
charges assessed to WAPA-SN by BANC based on net energy load within the
WAPA-SN Sub-Balancing Authority Area.

Formula Rate

The formula rate for EIM Administrative Service includes three
components:
Component 1
EIM Administrative Service costs shall be sub-allocated to WAPA-
SN's transmission customers based on load ratio share for the time in
which WAPA-SN incurs EIM administrative costs.
Component 2
Any charges or credits associated with the creation, termination,
or modification to any tariff, contract, or rate schedule accepted or
approved by FERC or other regulatory body will be passed on to each
relevant customer. The charges or credits apply to the service to which
this rate methodology applies. When possible, WAPA-SN will pass through
charges or credits directly to the customer in the same manner WAPA-SN
is charged or credited. When not possible, the charges or credits will
be passed through using Component 1 of the formula rate.
Component 3
Any charges or credits from the Host Balancing Authority for
providing this service will be passed on to each relevant customer.
When possible, WAPA-SN will pass through charges and credits directly
to the customer in the same manner WAPA-SN is charged or credited. When
not possible, the charges or credits will be passed through using
Component 1 of the formula rate.

Billing

Billing will occur monthly.

Audit Adjustments

Rate Schedule CV-EIM4S1
(Supersedes Rate Schedule CV-EIM4S)

UNITED STATES DEPARTMENT OF ENERGY

Western Area Power Administration

Central Valley Project

Energy Imbalance Market

Energy Imbalance Service

Effective

October 1, 2024, through September 30, 2029, or until superseded,
whichever occurs earlier.

Available

In the area served by the Western Area Power Administration (WAPA),
Sierra Nevada Region (SN).

Applicable

This rate applies to WAPA-SN customers receiving Energy Imbalance
(EI) Service when WAPA-SN, as the Transmission Provider, is
participating in Energy Imbalance Market (EIM) and when the EIM has not
been suspended. To the extent WAPA-SN incurs EIM Administrative
Service-related costs from the EIM Entity during periods of market
suspension or contingency, this schedule will also apply to ensure that
WAPA-SN, as Transmission Provider, remains revenue neutral for its
participation in EIM.

Character and Conditions of Service

EI Service is provided when a difference occurs between the
scheduled and the actual delivery of energy to a load located within
the WAPA-SN Sub-Balancing Authority Area (Sub-BAA). WAPA-SN offers this
service when transmission service is used to serve load within the
WAPA-SN Sub-BAA.
Unless subsequently imposed by California Independent System
Operator (CAISO) as the Market Operator (MO) as part of the MO Tariff
and promulgated by WAPA-SN through rate proceedings, there shall be no
incremental transmission charge assessed for transmission use related
to the EIM. Transmission customers must have transmission service
rights, as set forth in Attachment S of WAPA's Tariff.

Formula Rate

The formula rate for EI Service includes three components:
Component 1
EI Service is the deviation of the transmission customer's metered
load compared to the load component of the Transmission Customer Base
Schedule settled as Uninstructed Imbalance Energy (UIE) for the period
of the deviation at the applicable Load Aggregation Point (LAP) price
where the load is located.
EI Service penalties are applied to deviations as follows unless
otherwise dictated by contract or policy: (1) negative deviations
(under-delivery), outside the deviation bandwidth, will be charged the
greater of 50 percent of the CAISO market price or 50 percent of WAPA-
SN's actual cost; and (2) positive deviations (over-delivery), outside
the deviation bandwidth, will be lost to the system, except for any
hour when WAPA-SN incurs a cost to dispose of the energy, in which
event the responsible party will bear that cost.
Deviations that occur due to actions taken to support reliability
will be resolved in accordance with existing contractual requirements.
Such actions include reserve activations or uncontrolled event
responses as directed by the responsible reliability authority such as
SBA, Host Balancing Authority (HBA), Reliability Coordinator, or
Transmission Operator.
Component 2
Any charges or credits associated with the creation, termination,
or modification to any tariff, contract, or rate schedule accepted or
approved by FERC or other regulatory body will be passed on to each
relevant customer. The charges or credits apply to the service to which
this rate methodology applies. When possible, WAPA-SN will pass through
charges or credits directly to the customer in the same manner WAPA-SN
is charged or credited. When not possible, the charges or credits will
be passed through using Component 1 of the formula rate.
Component 3
Any charges or credits from the HBA for providing this service will
be passed

[[Page 59097]]

on to each relevant customer. When possible, WAPA-SN will pass through
charges and credits directly to the customer in the same manner WAPA-SN
is charged or credited. When not possible, the charges or credits will
be passed through using Component 1 of the formula rate.

Billing

Billing will occur monthly.

Audit Adjustments

Rate Schedule CV-EIM9S1
(Supersedes Rate Schedule CV-EIM9S)

UNITED STATES DEPARTMENT OF ENERGY

Western Area Power Administration

Central Valley Project

Energy Imbalance Market

Generator Imbalance Service

Effective

October 1, 2024, through September 30, 2029, or until superseded,
whichever occurs earlier.

Available

In the area served by the Western Area Power Administration (WAPA),
Sierra Nevada Region (SN).

Applicable

This rate applies to WAPA-SN customers receiving Generator
Imbalance (GI) Service when WAPA-SN, as the Transmission Provider, is
participating in Energy Imbalance Market (EIM) and when the EIM has not
been suspended. To the extent WAPA-SN incurs EIM Administrative
Service-related costs from the EIM Entity during periods of market
suspension or contingency, this schedule will also apply to ensure that
WAPA-SN, as Transmission Provider, remains revenue neutral for its
participation in EIM.

Character and Conditions of Service

GI Service is provided when a difference occurs between the output
of EIM Non-Participating Resource located in the WAPA-SN Sub-Balancing
Authority (Sub-BAA), as reflected in the resource component of the
Transmission Customer Base Schedule, and the delivery schedule from
that generator to (1) another BAA, (2) the Balancing Authority of
Northern California (BANC) BAA, or (3) a load within the WAPA-SN Sub-
BAA.
Unless subsequently imposed by California Independent System
Operator (CAISO) as the Market Operator (MO) as part of the MO Tariff
and promulgated by WAPA-SN through rate proceedings, there shall be no
incremental transmission charge assessed for transmission use related
to the EIM. Transmission customers must have transmission service
rights, as set forth in Attachment S of WAPA's Tariff.

Formula Rate

The formula rate for GI Service includes three components:
Component 1
GI Service penalties are applied to deviations as follows unless
otherwise dictated by contract or policy: (1) negative deviations
(under-delivery), outside the deviation bandwidth, will be charged the
greater of 50 percent of the CAISO market price or 50 percent of WAPA-
SN's actual cost; and (2) positive deviations (over-delivery), outside
the deviation bandwidth, will be lost to the system, except for any
hour when WAPA-SN incurs a cost to dispose of the energy, in which
event the responsible party will bear that cost.
Deviations that occur due to actions taken to support reliability
will be resolved in accordance with existing contractual requirements.
Such actions include reserve activations or uncontrolled event
responses as directed by the responsible reliability authority such as
SBA, Host Balancing Authority (HBA), Reliability Coordinator, or
Transmission Operator.
To the extent that an entity incorporates intermittent resources,
deviations will be charged as follows unless otherwise dictated by
contract or policy: (1) negative deviations (under-delivery), outside
the deviation bandwidth, will be charged the greater of market price or
actual cost (no penalty); and (2) positive deviations (over-delivery),
outside the deviation bandwidth, will be lost to the system, except for
any hour where WAPA-SN incurs a cost, then that cost will be borne by
the responsible party.
Intermittent generators serving load outside of WAPA-SN's SBA will
be required to dynamically schedule or dynamically meter their
generation to another Balancing Authority. An intermittent resource,
for the limited purpose of these rate schedules, is an electric
generator that is not dispatchable and cannot store its output, and
therefore, cannot respond to changes in demand or respond to
transmission security constraints.
Component 2
Any charges or credits associated with the creation, termination,
or modification to any tariff, contract, or rate schedule accepted or
approved by FERC or other regulatory body will be passed on to each
relevant customer. The charges or credits apply to the service to which
this rate methodology applies. When possible, WAPA-SN will pass through
charges or credits directly to the customer in the same manner WAPA-SN
is charged or credited. When not possible, the charges or credits will
be passed through using Component 1 of the formula rate.
Component 3
Any charges or credits from the HBA for providing this service will
be passed on to each relevant customer. When possible, WAPA-SN will
pass through charges and credits directly to the customer in the same
manner WAPA-SN is charged or credited. When not possible, the charges
or credits will be passed through using Component 1 of the formula
rate.

Billing

Billing will occur monthly.

Audit Adjustments

[FR Doc. 2024-16029 Filed 7-19-24; 8:45 am]
BILLING CODE 6450-01-P

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