Notice2023-26049
Salt Lake City Area Integrated Projects and Colorado River Storage Project-Rate Order No. WAPA-206
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
November 27, 2023
Effective
January 1, 2024
Issuing agencies
Energy DepartmentWestern Area Power Administration
Abstract
The provisional fixed rates for the Salt Lake City Area Integrated Projects (SLCA/IP) firm power service and the formula rates for the Colorado River Storage Project (CRSP) transmission services, ancillary services, sale of surplus products, and joint dispatch transmission service have been confirmed, approved, and placed into effect on an interim basis. The firm power rates under SLCA/IP Firm Power Rate Schedule SLIP-F12 expire December 31, 2023. Western Area Power Administration's (WAPA) CRSP Management Center (CRSP MC) is renewing all SLCA/IP and CRSP rates under one Federal Register notice (FRN), making all rates effective for the same period. These new rates replace existing firm power, transmission, ancillary services, sale of surplus products, and joint dispatch transmission service rates under Rate Orders No. WAPA-190, WAPA-195, and WAPA-199.
Full Text
<html>
<head>
<title>Federal Register, Volume 88 Issue 226 (Monday, November 27, 2023)</title>
</head>
<body><pre>
[Federal Register Volume 88, Number 226 (Monday, November 27, 2023)]
[Notices]
[Pages 82880-82890]
From the Federal Register Online via the Government Publishing Office [<a href="http://www.gpo.gov">www.gpo.gov</a>]
[FR Doc No: 2023-26049]
-----------------------------------------------------------------------
DEPARTMENT OF ENERGY
Western Area Power Administration
Salt Lake City Area Integrated Projects and Colorado River
Storage Project--Rate Order No. WAPA-206
AGENCY: Western Area Power Administration, DOE.
ACTION: Notice of rate order concerning firm power fixed rates and
transmission services, ancillary services, sale of surplus products,
and joint dispatch transmission service formula rates.
-----------------------------------------------------------------------
SUMMARY: The provisional fixed rates for the Salt Lake City Area
Integrated Projects (SLCA/IP) firm power service and the formula rates
for the Colorado River Storage Project (CRSP) transmission services,
ancillary services, sale of surplus products, and joint dispatch
transmission service have been confirmed, approved, and placed into
effect on an interim basis. The firm power rates under SLCA/IP Firm
Power Rate Schedule SLIP-F12 expire December 31, 2023. Western Area
Power Administration's (WAPA) CRSP Management Center (CRSP MC) is
renewing all SLCA/IP and CRSP rates under one Federal Register notice
(FRN), making all rates effective for the same period. These new rates
replace existing firm power, transmission, ancillary services, sale of
surplus products, and joint dispatch transmission service rates under
Rate Orders No. WAPA-190, WAPA-195, and WAPA-199.
DATES: The provisional rates under Rate Schedules SLIP-F13, SP-NW6, SP-
PTP10, SP-NFT9, SP-UU3, SP-EI6, SP-SSR6, SP-SS2, and SP-NFJDT are
effective on the first day of the first full billing period beginning
on or after January 1, 2024, and will remain in effect through December
31, 2028, pending confirmation and approval by the Federal Energy
Regulatory Commission (FERC) on a final basis or until superseded.
Pursuant to 10 CFR 903.21(b), the WAPA Administrator has set the
effective date to align with the expiration of the existing rate.
FOR FURTHER INFORMATION CONTACT: Rodney Bailey, CRSP Manager, Colorado
River Storage Project Management Center, Western Area Power
Administration, 1800 South Rio Grande Avenue, Montrose, CO 81401, 970-
252-3000, or email: <a href="/cdn-cgi/l/email-protection#8bc8d9d8dbc6c8a6f9eaffeea6eaefe1cbfceafbeaa5ece4fd"><span class="__cf_email__" data-cfemail="fdbeafaeadb0bed08f9c8998d09c9997bd8a9c8d9cd39a928b">[email protected]</span></a>; or Tamala Gheller, Rates
Manager, Colorado River Storage Project Management Center, Western Area
Power Administration, 970-240-6545, or email: <a href="/cdn-cgi/l/email-protection#12514041425f513f607366773f73767852657362733c757d64"><span class="__cf_email__" data-cfemail="a8ebfafbf8e5eb85dac9dccd85c9ccc2e8dfc9d8c986cfc7de">[email protected]</span></a>.
SUPPLEMENTARY INFORMATION: On May 12, 2022, FERC approved and confirmed
Rate Schedule SLIP-F12 for Firm Power Service under Rate Order No.
WAPA-199 on a final basis through December 31, 2023.\1\ On March 18,
2022, FERC approved and confirmed Rate Schedule SP-NFJDT for Joint
Dispatch Transmission Service under Rate Order No. WAPA-195 on a final
basis through September 30, 2024.\2\ On December 17, 2020, FERC
approved and confirmed the following rate schedules under Rate Order
No. WAPA-190 on a final basis through September 30, 2025: \3\ SLIP-F11
for Firm Power Service (superseded by SLIP-F12 under WAPA-199), SP-NW5
for Network Integration Transmission Service, SP-PTP9 for Firm Point-
to-Point Transmission Service, SP-NFT8 for Non-Firm Point-to-Point
Transmission Service, SP-UU2 for Unreserved Use Penalties, SP-E15 for
Energy and Generation Imbalance, SP-SSR5 for Operating Reserves--
Spinning and Supplemental Reserve Services, and SP-SS1 for Sale of
Surplus Products.
---------------------------------------------------------------------------
\1\ Order Confirming and Approving Rate Schedule on a Final
Basis, FERC Docket No. EF 22-1-000 (179 FERC ] 62,085 (2022)).
\2\ Order Confirming and Approving Rate Schedule on a Final
Basis, FERC Docket No. EF 21-7-000 (178 FERC ] 62,154 (2022)).
\3\ Order Confirming and Approving Rate Schedules on a Final
Basis, FERC Docket No. EF 20-7-000 (173 FERC ] 61,230 (2020)).
---------------------------------------------------------------------------
On June 22, 2023, Western Area Power Administration (WAPA)
published a Federal Register notice (Proposal FRN) (88 FR 40813)
proposing new 5-year rates for firm power service, transmission
services, ancillary services, sale of surplus products, and joint
dispatch transmission service. The Proposal FRN initiated a 90-day
public consultation and comment period and set forth the date and
location of the public information and the public comment forums. The
firm power rate is a fixed rate. The transmission services, ancillary
services, surplus products, and joint dispatch rates continue the
formula-based methodology that includes an annual update to the
financial and load data in the applicable rate formulas. The inputs
into the formulas and resulting charges under the rates will be
annually updated on October 1.
On August 28, 2023, CRSP MC sent email notice to extend the Comment
and Consultation Period for Proposed WAPA-206 from September 1, 2023,
through October 3, 2023. The intent of this extension was to provide
interested parties additional time to review and provide comments
related to the results of the Bureau of Reclamation's August 24-month
study data, along with other aspects of the rate proposal made
available by WAPA during the original comment period.
Legal Authority
By Delegation Order No. S1-DEL-RATES-2016, effective November 19,
2016, the Secretary of Energy delegated: (1) the authority to develop
power and transmission rates to the WAPA Administrator; (2) the
authority to confirm, approve, and place such rates into effect on an
interim basis to the Deputy Secretary of Energy; and (3) the authority
to confirm, approve, and place into effect on a final basis, or to
remand or disapprove such rates, to FERC. By Delegation Order No. S1-
DEL-S3-2023, effective April 10, 2023, the Secretary of Energy also
delegated the authority to confirm, approve, and place such rates into
effect on an interim basis to the Under Secretary for Infrastructure.
By Redelegation Order No. S3-DEL-WAPA1-2023, effective April 10, 2023,
the Under Secretary for Infrastructure further redelegated the
authority to confirm, approve, and place such rates
[[Page 82881]]
into effect on an interim basis to WAPA's Administrator. This rate
action is issued under Redelegation Order No. S3-DEL-WAPA1-2023 and
Department of Energy procedures for public participation in rate
adjustments set forth at 10 CFR part 903.\4\
---------------------------------------------------------------------------
\4\ 50 FR 37835 (Sept. 18, 1985) and 84 FR 5347 (Feb. 21, 2019).
---------------------------------------------------------------------------
Following DOE's review of CRSP MC's proposal, Rate Order No. WAPA-
206, which provides the fixed rates for the SLCA/IP firm power service
and the formula rates for the CRSP transmission services, ancillary
services, sale of surplus products, and joint dispatch transmission
service, is hereby confirmed, approved, and placed into effect on an
interim basis. By this order, I may be placing the rates into effect in
less than 30 days to meet contractual obligations and avoid financial
difficulties. WAPA will submit Rate Order No. WAPA-206 to FERC for
confirmation and approval on a final basis.
DEPARTMENT OF ENERGY
ADMINISTRATOR, WESTERN AREA POWER ADMINISTRATION
In the Matter of: Western Area Power Administration Colorado
River Storage Project Management Center Rate Adjustment for the Salt
Lake City Area Integrated Projects Firm Power Rates and the Colorado
River Storage Project Transmission Services, Ancillary Services,
Sale of Surplus Products, and Joint Dispatch Transmission Service
Rate Order No. WAPA-206
Order Confirming, Approving, and Placing the Fixed Firm Power Rates for
the Salt Lake City Area Integrated Projects and the Formula Rates for
Transmission Services, Ancillary Services, Sale of Surplus Products,
and Joint Dispatch Transmission Service for the Colorado River Storage
Project Into Effect on an Interim Basis
The rates in Rate Order No. WAPA-206 are established following
section 302 of the Department of Energy (DOE) Organization Act (42
U.S.C. 7152).\5\
---------------------------------------------------------------------------
\5\ This Act transferred to, and vested in, the Secretary of
Energy the power marketing functions of the Secretary of the
Department of the Interior and the Bureau of Reclamation
(Reclamation) under the Reclamation Act of 1902 (ch. 1093, 32 Stat.
388), as amended and supplemented by subsequent laws, particularly
section 9(c) of the Reclamation Project Act of 1939 (43 U.S.C.
485h(c)) and other acts that specifically apply to the projects
involved.
---------------------------------------------------------------------------
By Delegation Order No. S1-DEL-RATES-2016, effective November 19,
2016, the Secretary of Energy delegated: (1) the authority to develop
power and transmission rates to the Western Area Power Administration
(WAPA) Administrator; (2) the authority to confirm, approve, and place
such rates into effect on an interim basis to the Deputy Secretary of
Energy; and (3) the authority to confirm, approve, and place into
effect on a final basis, or to remand or disapprove such rates, to the
Federal Energy Regulatory Commission (FERC). By Delegation Order No.
S1-DEL-S3-2023, effective April 10, 2023, the Secretary of Energy also
delegated the authority to confirm, approve, and place such rates into
effect on an interim basis to the Under Secretary for Infrastructure.
By Redelegation Order No. S3-DEL-WAPA1-2023, effective April 10, 2023,
the Under Secretary for Infrastructure further redelegated the
authority to confirm, approve, and place such rates into effect on an
interim basis to WAPA's Administrator. This rate action is issued under
Redelegation Order No. S3-DEL-WAPA1-2023 and DOE procedures for public
participation in rate adjustments set forth at 10 CFR part 903.\6\
---------------------------------------------------------------------------
\6\ 50 FR 37835 (Sept. 18, 1985) and 84 FR 5347 (Feb. 21, 2019).
---------------------------------------------------------------------------
Acronyms, Terms, and Definitions
As used in this Rate Order, the following acronyms, terms, and
definitions apply:
Basin Fund: Upper Colorado River Basin Fund--a revolving fund that
operates without annual appropriations.
Capacity: The electric capability of a generator, transformer,
transmission circuit, or other equipment. It is expressed in kilowatts
(kW).
Capacity Rate: The rate which sets forth the charges for capacity.
It is expressed in $/kWmonth and applied to each kW delivered to each
Customer.
CRC: Cost Recovery Charge--an additional surcharge on all SHP
energy deliveries, which are long-term energy sales provided under
WAPA's SLCA/IP firm electric service contracts.
CRCM: The North American Electric Reliability Corporation (NERC)-
registered Joint Dispatch Transmission Service Provider for WAPA's
Colorado River Storage Project Management Center (CRSP MC) transmission
facilities included in the Transmission System within the Western
Energy Imbalance Service (WEIS) Market Footprint.
CROD: Contract Rate of Delivery--the maximum amount of capacity
made available to a Preference Customer for a period specified under a
contract.
CRMMS: Colorado River Mid-term Modeling System--one of two river
system models developed and maintained by Reclamation to support
operational decision-making and planning for the Colorado River Basin.
CRSS: Colorado River Simulation System--is one of two river system
models developed and maintained by the Bureau of Reclamation to support
operational decision-making and planning for the Colorado River Basin.
Customer: Firm electric service customer(s) contractually receiving
SLCA/IP power and energy.
Customer Rate Brochure: A document prepared for public distribution
explaining the rationale and background for the information contained
in the Proposed FRN and in this rate order.
CY: Calendar Year. When used in the CRC it is the 12-month period
(January through December) the CRC is in effect.
DSA: Deliverable Sales Amount--marketable generation level, above
which WAPA will forgo Purchased Power.
Energy Rate: The rate which sets forth the charge for energy. It is
expressed in mills/kWh and applied to each kWh delivered to each
Customer.
Firm: A type of product or service available at the time requested
by the Customer.
FRN: Federal Register Notice--a document published in the Federal
Register.
FY: WAPA's fiscal year, October 1 to September 30.
GWh: Gigawatthour--the electrical unit of energy that equals 1
billion watthours or 1 million kWh.
Integrated Projects: The resources and revenue requirements of the
Collbran, Dolores, Rio Grande, and Seedskadee projects blended with the
CRSP to create the SLCA/IP resources and rate.
kW: Kilowatt--the electrical unit of capacity that equals 1,000
watts.
kWh: Kilowatt-hour--the electrical unit of energy that equals 1,000
watts in 1 hour.
kWmonth: Kilowatt-month--the electrical unit of the monthly amount
of capacity.
Load: The amount of electric power or energy delivered or required
at any specified point(s) on a system.
Load Factor: The percentage of actual kWh delivered on a system in
a designated period of time, as opposed to the total possible kWh that
could be delivered on a system in a designated period time.
Mill: A monetary denomination of the United States that equals one
tenth of a cent or one thousandth of a dollar.
MAF: Million Acre-Feet--the number of gallons of water required to
cover 1 million acres, 1 foot in depth.
Mills/kWh: Mills per kilowatthour--the unit of charge for energy.
MOA: Memorandum of Agreement concerning the Basin Fund for Upper
Division States to share their
[[Page 82882]]
apportionment with each other through FY 2037. This agreement reduces
the impact on the CRSP Firm Power rate by eliminating the collection of
power revenue beyond the amount needed to repay the costs for
participating irrigation projects.
MW: Megawatt--the electrical unit of capacity that equals 1 million
watts or 1,000 kilowatts.
MWh: One million watt-hours of electric energy. A unit of
electrical energy which equals 1 megawatt of power used for 1 hour.
NEPA: National Environmental Policy Act of 1969, as amended.
New Rate Trigger: Under a New Rate Trigger, CRSP-MC would reassess
an implemented CRC when the new rate goes into effect to determine if
the implemented CRC should be superseded or terminated.
OATT: Open Access Transmission Tariff, including all schedules or
attachments thereto, as amended from time to time and approved by FERC.
O&M: Operation and maintenance expenses.
Order RA 6120.2: DOE Order outlining Power Marketing Administration
financial reporting and rate-making procedures.
Participating Projects: The Dolores and Seedskadee projects
participating with CRSP according to the CRSP Act 1956.
Pinch Point: The year in the PRS that requires the greatest amount
of revenue.
Power: Capacity and energy.
Project Use: Power used to operate SLCA/IP and CRSP facilities
under Reclamation Law.
Proposed Rate: A rate that has been recommended by WAPA.
Provisional Rate: A rate which has been confirmed, approved, and
placed into effect on an interim basis by the Secretary or his/her
designee.
Power Repayment Study (PRS): Defined in DOE Order RA 6120.2 as a
study portraying the annual repayment of power production and
transmission costs of a power system through the application of
revenues over the repayment period of the power system. The study
shows, among other items, estimated revenues and expenses, year by
year, over the remainder of the power system's repayment period (based
upon conditions prevailing over the cost evaluation period), the
estimated amount of Federal investment amortized during each year, and
the total estimated amount of Federal investment remaining to be
amortized.
Ratesetting PRS: The SLIP PRS used for the rate adjustment
proposal.
Reclamation Law: A series of Federal laws. Viewed as a whole, these
laws create the originating framework under which WAPA markets power.
Revenue Requirement: The revenue required by the PRS to recover O&M
expenses, purchased power and transmission service expenses, interest,
deferred expenses, and repayment of Federal investments, or other
assigned costs.
SHP: Sustainable Hydro Power (long-term SLCA/IP hydro capacity with
energy).
SLIP PRS: CRSP PRS that includes the Collbran, Dolores, Rio Grande,
and Seedskadee revenue requirements.
Supporting Documentation: A book of data that supports this rate
action and associated rates brochure.
Work Plan: An estimate of costs that are expected to become the
Congressional Budget for WAPA and Reclamation. Also known as a Work
Program.
WRF: Western Replacement Firming--WRF is optional purchased power
to firm to customers' Sustainable Hydropower (SHP) allocation levels,
the cost of which is passed through to firm power customers under a
separate charge for those customers electing WRF.
Effective Date
The Provisional Rate Schedules SLIP-F13, SP-NW6, SP-PTP10, SP-NFT9,
SP-UU3, SP-EI6, SP-SSR6, SP-SS2, and SP-NFJDT will take effect on the
first day of the first full billing period beginning on or after
January 1, 2024, and will remain in effect through December 31, 2028,
pending approval by FERC on a final basis or until superseded.
Public Notice and Comment
CRSP MC followed the Procedures for Public Participation in Power
and Transmission Rate Adjustments and Extensions, 10 CFR part 903, in
developing these rates. CRSP MC took the following steps to involve
interested parties in the rate process:
1. On June 22, 2023, a Federal Register notice (88 FR 40813)
(Proposal FRN) announced the proposed rates and launched a 71-day
public consultation and comment period, set to end on September 1,
2023. The original public consultation and comment period was shorter
than 90 days, in accordance with 10 CFR 903.14(a). The CRSP MC
shortened the comment period to less than 90 days for good cause. There
was a delay in processing the Proposal FRN resulting from the
unexpected loss of key rates personnel. Decreasing the comment period
timeframe was deemed necessary to implement the new rate effective
January 1, 2024.
2. On June 22, 2023, CRSP MC notified all Customers and interested
parties of the proposed rates and provided a copy of the Proposal FRN
and the link to the WAPA-206 rate action site at: <a href="http://www.wapa.gov/about-wapa/regions/crsp-2/rates/rate-order-206">www.wapa.gov/about-wapa/regions/crsp-2/rates/rate-order-206</a> (website).
3. On July 19, 2023, CRSP MC held a Public Information Forum (PIF)
in Salt Lake City, Utah. The PIF was held both in-house, as well as
virtually. CRSP MC's representatives explained the proposed rates,
answered questions, and gave notice that additional information was
made available in the Customer Rate Brochure.
4. On August 15, 2023, CRSP MC held a virtual public comment forum
to provide an opportunity for customers and other interested parties to
comment for the record.
5. During the consultation and comment period, which ended on
October 3, 2023, CRSP MC received four oral comments (two at the August
15, 2023, and two at the September 19, 2023, public comment forums) and
eight written sets of comments. CRSP MC posted an updated Rate Brochure
and Supporting Documents to the website on September 19, 2023. The
other comments and CRSP MC's responses are addressed below.
6. On August 18, 2023, CRSP MC held a webinar on purchased power
data sources and calculations.
7. On August 28, 2023, CRSP MC notified customers and interested
parties via email, extending the consultation and comment period from
September 1, 2023, to October 3, 2023. The comments received during the
extended comment period and CRSP MC's responses are addressed below.
CRSP MC posted the comments to the website on October 12, 2023. All
comments have been considered in the preparation of this Rate Order.
Oral comments were received from the following organization:
Colorado River Energy Distributors Association (CREDA)
Arizona Electric Power Cooperative (AEPCO)
Written comments were received on behalf of the following
organizations during the original and extended comment periods:
Arizona Electric Power Cooperative (AEPCO)
Colorado River Energy Distributors Association (CREDA)
Electrical District No. 4 of Pinal County (ED4)
Electrical District No. 7 of Maricopa County (ED7)
Irrigation & Electrical Districts Association of Arizona (IEDA)
[[Page 82883]]
Maricopa Water District (MWD)
Navajo Tribal Utility Authority (NTUA)
Wyoming Municipal Power Agency (WMPA)
Power Repayment Study--Firm Power Service Rate Discussion
CRSP MC prepares PRSs each FY to determine if revenues will be
sufficient to repay, within the required time, all costs assigned to
the SLCA/IP. Repayment criteria are based on applicable laws and
legislation as well as policies including DOE Order RA 6120.2. Under
the existing rate methodology, rates for firm power service are
designed to recover an annual revenue requirement that includes power
investment repayment, aid to irrigation repayment, interest, purchase
power, O&M, and other expenses within the allowable period. To meet the
Cost Recovery Criteria outlined in DOE Order RA 6120.2, the CRSP MC
developed a rate adjustment to demonstrate sufficient revenues will be
collected under the Provisional Rates to meet future obligations. The
revenue requirement for SLCA/IP firm power service decreased slightly,
while the energy and capacity rates are set to remain the same, as
indicated in Table 1:
Table 1--Comparison of Revenue Requirements and Rates
----------------------------------------------------------------------------------------------------------------
Existing Provisional
requirements under requirements under
Firm power service SLIP-F12 (December SLIP-F13 (January Percent change
1, 2021) 1, 2024)
----------------------------------------------------------------------------------------------------------------
Revenue Requirement (million $)......................... $181,197 $180,239 -0.5
Energy Rate (mills/kWh)................................. 12.36 12.36 0.0
Capacity Rate ($/kWmonth)............................... 5.25 5.25 0.0
----------------------------------------------------------------------------------------------------------------
Statement of Revenue and Related Expenses
Table 2 provides a comparison of the average annual expense data
for the SLCA/IP firm power service revenue requirement through the
rate-setting period.
Table 2--Annual Revenue Requirements and Firm Power Rates Comparison Table
----------------------------------------------------------------------------------------------------------------
Existing rate, Provisional
SLIP-F12 rate, SLIP-F13 Difference
($1,000) ($1,000) ($1,000)
----------------------------------------------------------------------------------------------------------------
Rate Setting Period............................................. 2022-2045 2024-2045 ..............
Revenue Distribution:
Expenses:
O&M............................................................. $103,095 $111,548 $8,453
Purchase Power.................................................. $833 $1,136 $303
Transmission.................................................... $8,984 $7,000 ($1,984)
Integrated Projects requirements................................ $7,043 $7,501 $458
Interest........................................................ $6,207 $11,152 $4,945
Other........................................................... $13,547 $13,508 ($39)
-----------------------------------------------
Total Expenses.............................................. $139,709 $151,845 $12,136
----------------------------------------------------------------------------------------------------------------
Principal Payments:
Capitalized Expenses (deficits)................................. $838 $0 ($838)
Replacements.................................................... $29,581 $13,702 ($15,879)
Original Project and Additions.................................. $1,846 $936 ($910)
Irrigation...................................................... $9,223 $13,756 $4,533
-----------------------------------------------
Total Principal Payments.................................... $41,488 $28,394 ($13,094)
----------------------------------------------------------------------------------------------------------------
Annual Revenue Requirement...................................... $181,197 $180,239 ($958)
Composite Rate.................................................. 30.51 31.38 2.85%
Energy Rate (mills/kWh)......................................... 12.36 12.36 0.00%
Capacity Rate ($/kWmonth)....................................... 5.25 5.25 0.00%
----------------------------------------------------------------------------------------------------------------
Any purchased power expense required to supplement hydropower
deliveries up to contractual levels will be passed through to Customers
under a separate charge, WRF, which would be in addition to the rate
for hydropower deliveries. Any Customer not receiving WRF will not be
charged the purchased power charge and would receive its proportionate
amount of the DSA capacity and energy from WAPA each month.
SLCA/IP Firm Power Rate
The revenue requirement for Rate Schedule SLIP-F13 is based on FY
2022 financial data, WAPA and Reclamation's FY 2025 Work Plans, and
Reclamation's August 2023 24-Month Study (24-month Study) and the April
2023 CRSS traces.
For the first two years of the effective rate period, FY 2024 and
FY 2025, CRSP MC is basing sales in the rate on forecasted generation
from Reclamation's August 2023 24-month Study and is basing sales for
the last
[[Page 82884]]
three years of the effective rate period, FY 2026 through FY 2028, on
forecasted generation from Reclamation's April 2023 CRSS Traces.
Additionally, Rate Schedule SLIP-F13 includes actions CRSP MC will take
should Lake Powell's water level drop below the level at which power
can be generated.
CRSP MC will not automatically purchase firming power to SHP
levels. For those Customers who elect, CRSP MC will purchase WRF power
as a pass-through cost, at market rates, up to SHP levels. CRSP MC will
purchase power to firm to the forecasted generation level, referred to
as the DSA. CRSP MC will continue to use the DSA methodology
established in Rate Order No. WAPA-199 to address drought conditions in
the southwestern United States and volatile purchased power costs. The
DSA will be updated quarterly as shown in Table 3. Customers will have
at least 14 days to affirmatively select WRF for each quarter.
Quarterly notices provide flexibility in responding to changes in
hydrology and will not impact the rates. Customers can elect the full
quarter or specific months within the quarter.
Table 3--Deliverable Sales Amount Quarterly Updates to Customers
----------------------------------------------------------------------------------------------------------------
Customer notification
Quarter 24-Month study (estimated) Start date
----------------------------------------------------------------------------------------------------------------
Q2 Jan-Mar.......................... November............... November 20........... January 1.
Q3 Apr-Jun.......................... February............... February 20........... April 1.
Q4 Jul-Sep.......................... May.................... May 20................ July 1.
Q1 Oct-Dec.......................... August................. August 20............. October 1.
----------------------------------------------------------------------------------------------------------------
Deliverable Sales Amount
Under the DSA methodology, sales are limited to projected
generation, and CRSP MC will make firming purchases up to the
forecasted DSA level. FY 2022 and FY 2023 costs for operational
expenses necessary to meet DSA have been included in the rate. Outyear
DSA energy projections are based on Reclamation's August 2023 24-month
study (for FY 2024 and FY 2025) and Reclamation's April 2023 CRMMS
study through the end of the rate setting period (for FY2026, FY2027,
and FY2028). CRSP MC will continue to offer the WRF product. WRF is
optional purchased power to firm to customers' Sustainable Hydropower
(SHP) allocation levels, the cost of which is passed through to firm
power customers under a separate charge for those customers electing
WRF. Both DSA and WRF will continue to be updated quarterly using the
applicable 24-month study from Reclamation. WRF will continue to be
billed as it is requested to match cost collection with cost
occurrence.
Any customer electing not to receive its share of the purchased
power costs through WRF will not be charged for WRF. These customers
will receive a proportionate amount of capacity and energy from CRSP MC
each month under the DSA, charged at the proposed firm power rate,
reflecting projected hydropower generation levels.
Cost Recovery Charge
CRSP MC maintains the ability to implement a CRC, if necessary. The
CRC is a mechanism to adequately recover and maintain a sufficient
balance in the Basin Fund in the event projected expenses significantly
exceed projected revenue estimates. The Basin Fund is a revolving fund
and operates without annual appropriations. The CRC is an additional
surcharge on all SHP energy deliveries, which are long-term energy
sales provided under WAPA's SLCA/IP firm electric service contracts.
The CRC may be implemented when, among other things, the Basin Fund's
cash balance is at risk due to low hydropower generation, high prices
for firming power, or emergency capitalized investment funding. The CRC
is based only on Basin Fund cash analysis and is independent of the
SLCA/IP PRS calculations.
CRSP Transmission Services
In accordance with WAPA's OATT, CRSP MC offers Network Integration
Transmission Service, Firm, Non-Firm Point-to-Point, and Joint Dispatch
Transmission Services (JDTS). These services include the transmission
of energy to points of delivery on the CRSP interconnected high-voltage
system, which is comprised of transmission lines, substations, and
related facilities. The transmission rates include the cost for
Scheduling, System Control, and Dispatch Service. The CRSP MC is
proposing no change to the formula rates associated with the CRSP
Transmission Services; only to make the effective dates align with the
SLCA/IP firm power rate time period. The Provisional Rates are as
described in the respective Rate Schedules and apply to transmission-
only sales.
Network Integration Transmission Service, Firm, and Non-Firm Point-to-
Point Transmission Services, Formula Rates SP-NW6 (Network), SP-PTP10
(Firm) and SP-NFT9 (Non-Firm)
The Provisional Rates are as described in the Rate Schedules and
apply to transmission-only sales. The cost of transmission service for
WAPA's SLCA/IP long-term, firm electric service will continue to be
included in the SLCA/IP firm power rate.
Joint Dispatch Transmission Service, Formula Rate SP-NFJDT
Rate Schedule SP-NFJDT is used when CRCM is participating in the
WEIS market. JDTS customers shall compensate the CRSP Transmission
Service Provider for JDTS commensurate with the receipt or delivery of
energy dispatched for the JDTS Customer pursuant to the WEIS Tariff
under the formula rate described herein.
Unreserved Use Penalties, Formula Rate SP-UU3
Unreserved Use occurs when an eligible customer uses transmission
service that it has not reserved, or a transmission customer uses
transmission service in excess of its reserved capacity. Unreserved Use
may also include a customer's failure to curtail transmission when
requested. The Transmission Customer shall compensate the CRSP
Transmission Service Provider each month for any unreserved use of the
transmission system under the applicable transmission service rates as
outlined herein.
Ancillary Services
Energy Imbalance (EI) and Generator Imbalance (GI) Services, Formula
Rate SP-EI6
No changes to the rate schedule for energy imbalance and generator
imbalance under proposed Rate Schedule SP-EI6. EI/GI Services are
provided through the Western Area Colorado Missouri (WACM) Balancing
Authority under Rate Schedules L-AS4 and L-AS9, or as superseded.
[[Page 82885]]
Spinning and Supplemental Reserves Services, Formula Rate SP-SSR6
No changes to the rate schedule for spinning and supplemental
reserves services under proposed Rate Schedule SP-SSR6. The
transmission customer serving loads within the transmission provider's
balancing authority must acquire Spinning and Supplemental Reserve
services from CRSP, from a third party, or by self-supply.
Sale of Surplus Products, Formula Rate SP-SS2
No changes to the rate schedule for sale of surplus products under
proposed Rate Schedule SP-SS2. The charge for each product will be
determined at the time of the sale based on market rates, plus
administrative costs. The customer will be responsible for acquiring
transmission service necessary to deliver the product(s), for which a
separate charge may be incurred.
Comments
WAPA received 41 separate oral and/or written comments during the
public consultation and comment period. The comments expressed have
been paraphrased and/or combined, where appropriate, without
compromising the meaning of the comments.
Comments on Firm Power Rates
A. Comment: Commentors recommended CRSP MC implement a 2-year Firm
Power rate instead of the proposed 5-year rate, due to concerns with
instability of hydrological conditions and potential developing market
situations.
Response: CRSP MC is implementing a 5-year rate to help with long
term rate stability and based on established business processes will
continue to annually reassess rate adequacy versus changes to budgets,
hydrological conditions, and any other rate affecting factors. If CRSP
MC identifies factors prompting an update to the rate, CRSP MC will
initiate a public process to implement a new rate.
B. Comment: A commentor expressed support for CRSP MC's goal to
maintain the rate the same as currently in effect per WAPA-199.
Response: CRSP MC appreciates the feedback.
Comment on Transmission
A. Comment: A commentor asked that if customers are only getting
DSA levels, with little to no firming, why does CRSP MC forecast
transmission demand used to develop the CRSP transmission rate in
excess of reasonably anticipated levels of Sustainable Hydroelectric
Power (``SHP''), DSA, and the CROD, over portions of the forecast
period thus restricting the transmission capacity from being offered to
others to enable renewable generators to replace aging coal plants;
plus, this over statement of reservations increases the costs to the
SLCA/IP power rates.
Response: The CRSP MC has, for well over a decade, held the current
amount of point-to-point transmission capacity. CRSP MC reasonably
projects this amount of capacity will continue to be needed within the
rate-making window. Although DSA levels reflect projected generation,
they remain uncertain due to changes in water releases. Firming
purchases are often necessary even in months where hydropower
generation is higher than normal; firming purchases and excess energy
sales are made in shoulder hours as hydrologic operations cannot
respond immediately to customer schedules. CRSP MC is unique in its use
of point-to-point transmission, as opposed to network transmission
service, but has found that point-to-point reservations best ensure it
can successfully operate during periods when water releases and energy
generation are higher than normal, such what occurred in the summer of
2003, as well as respond to outage conditions allowing rerouting of
energy schedules without disruption, as well as to meet requirements of
power replacement programs.
Comments on Purchased Power
A. Comment: A commentor stated that WAPA-199's primary objective
was to maintain a sufficient balance in the Basin Fund, while
obligating the responsibility of replacement power to the customers.
With almost two years of operating experience under that paradigm, they
recommended that CRSP MC continue to maintain the same rate by
including $0 in the WAPA-206 purchased power line item, consistent with
WAPA-199. They also noted that WAPA-206 continues the customers'
responsibility of making replacement power purchases, which reduces the
Basin Fund's obligations. Given the positive hydrology the Colorado
River system experienced this spring, and the results of the August
2023 24-month study projections, and in support of a two-year rate, the
Basin Fund should be able to support any firming purchases required for
operational purposes.
Response: Due to timing-based operational needs, CRSP MC continues
to experience purchased power expenses to meet customer energy needs,
especially in shoulder hours of the scheduling day. CRSP MC's rate
design takes into account those timing based operational purchased
power expenses.
Comments on Other
A. Comment: A commentor recommended that CRSP MC and Reclamation
continue to evaluate the cost assignment based on the concept of
``beneficiary pays''.
Response: CRSP MC appreciates the comment. CRSP MC agrees with the
concept of beneficiary pays and continues to work with Reclamation to
update cost-allocations as appropriate.
B. Comment: Commentor requested that $1.624 million be removed from
the ``Other Expense'' category based on pending legislative changes
supported by the seven Colorado River Basin States, for the Colorado
River Salinity Control Program, which changes center around non-
reimbursable and reducing the Basin Fund's obligations.
Response: At the time Reclamation provides a final decision
regarding the Salinity obligation, those assumptions, along with all
annual results of operations, will be vetted through the SLIP PRS for
annual rate impact assessment. If within those annual assessments we
find there is a need to amend or adjust the existing rate, we will then
engage customers and the public to inform them of current
recommendations. As of August 2023, Reclamation shared that the
proposed language to the Salinity Control Act 23639 is still undergoing
discussion.
C. Comment: A commenter appreciated CRSP MC's inclusion of a rate
brochure statement that the proposed rate does not ``imply any
interpretation of or waiver of any of the terms and conditions of the
Firm Electric Service contracts.'' While the rate may reflect an
operational paradigm which hopefully will improve in coming years, the
sanctity of the FES contracts has not changed with the rate structures
originally proposed in WAPA-199 and will continue with WAPA-206.
Response: CRSP MC appreciates the comment and support.
Comments on CRSP's Proposal To Participate in the Southwest Power Pool
Regional Transmission Organization
A. Comment: A commenter stated that WAPA has never provided any
transparent, documented analysis of the impact of [WAPA's] decision to
pursue SPP membership on CRSP contractors' costs. This void in the
administrative record makes it difficult to see how WAPA expects to
make the showing required by Section 3 of Delegation Order No. 204-108,
58 FR 59716, 59717
[[Page 82886]]
(1993) for review and confirmation of the WAPA-206 rates: that ``the
rates are the lowest possible to customers consistent with sound
business principles.''
Response: These concerns have been addressed in a separate public
process specific to this subject. On April 28, 2023, WAPA published an
FRN (88 FR 26298) with a ``Recommendation for the Western Area Power
Administration's Rocky Mountain Region and Colorado River Storage
Project Management Center to Pursue Final Negotiations Regarding
Membership in the Southwest Power Pool Regional Transmission
Organization, and for the Upper Great Plains Region To Expand Its
Participation.'' WAPA engaged in outreach to customers and other
interested stakeholders via a public information meeting followed by a
question-and-answer session on May 11, 2023. WAPA then held a follow up
public question-and-answer session on May 25, 2023. WAPA reopened the
comment period and held an additional narrowly focused information
webinar and question-and-answer session on June 27, 2023. Over the
course of the 75-day public comment period, WAPA received 69 written
comment letters. The written comments and a summary of WAPA's responses
are available on WAPA's website: <a href="http://www.wapa.gov/about-wapa/key-topics-2/southwest-power-pool-membership">www.wapa.gov/about-wapa/key-topics-2/southwest-power-pool-membership</a>.
B. Comment: A commenter stated it has a good working relationship
with WAPA that allows the customer to import and export power necessary
for economic growth but is concerned that WAPA's expanded participation
in SPP could jeopardize the customer's ability to continue to do so
economically. The customer respectfully requests that any final
agreement on WAPA's membership and expanded participation in SPP
include provisions to protect the customer's existing contract rights.
Response: CRSP MC appreciates the comment. As responded to in a
previous comment, WAPA published a Federal Register notice (FRN) with a
``Recommendation for the Western Area Power Administration's Rocky
Mountain Region and Colorado River Storage Project Management Center to
Pursue Final Negotiations Regarding Membership in the Southwest Power
Pool Regional Transmission Organization, and for the Upper Great Plains
Region To Expand Its Participation'' on April 28, 2023. Information
about this process and proposal, as well as responses to customer
comments and questions, and decision documents are available on WAPA's
website: <a href="http://www.wapa.gov/about-wapa/key-topics-2/southwest-power-pool-membership">www.wapa.gov/about-wapa/key-topics-2/southwest-power-pool-membership</a>.
Certification of Rates
I have certified that the Provisional Rates for SLCA/IP firm power
and sales of surplus products and the CRSP transmission and ancillary
services under Rate Schedules SLIP-F13, SP-NW6, SP-PTP10, SP-NFT9, SP-
UU3, SP-EI6, SP-SSR6, SP-SS2, and SP-NFJDT are the lowest possible
rates, consistent with sound business principles. The Provisional Rates
were developed following administrative policies and applicable laws.
Availability of Information
Information used by CRSP MC to develop the Provisional Rates is
available for inspection and copying at the Colorado River Storage
Project Management Center, Western Area Power Administration, 1800
South Rio Grande Avenue, Montrose, CO 81401. Many of these documents
are also available on WAPA's website: <a href="http://www.wapa.gov/about-wapa/regions/crsp-2/rates">www.wapa.gov/about-wapa/regions/crsp-2/rates</a>.
Ratemaking Procedure Requirements
Environmental Compliance
WAPA has determined that this action fits within the following
categorical exclusion listed in appendix B to subpart D of 10 CFR
1021.410: B4.3 (Electric power marketing rate changes). Categorically
excluded projects and activities do not require preparation of either
an environmental impact statement or an environmental assessment.\7\ A
copy of the categorical exclusion determination is available on WAPA's
website: <a href="http://www.wapa.gov/about-wapa/regions/crsp-2/about-crsp/environment-3">www.wapa.gov/about-wapa/regions/crsp-2/about-crsp/environment-3</a>.
---------------------------------------------------------------------------
\7\ The determination was done in compliance with NEPA (42
U.S.C. 4321-4347); the Council on Environmental Quality Regulations
for implementing NEPA (40 CFR parts 1500-1508); and DOE NEPA
Implementing Procedures and Guidelines (10 CFR part 1021).
---------------------------------------------------------------------------
Determination Under Executive Order 12866
WAPA has an exemption from centralized regulatory review under
Executive Order 12866; accordingly, no clearance of this notice by the
Office of Management and Budget is required.
Submission to the Federal Energy Regulatory Commission
The Provisional Rates herein confirmed, approved, and placed into
effect on an interim basis, together with supporting documents, will be
submitted to FERC for confirmation and final approval.
Order
In view of the above, and under the authority delegated to me, I
hereby confirm, approve, and place into effect, on an interim basis,
Rate Order No. WAPA-206. The rates will remain in effect on an interim
basis until: (1) FERC confirms and approves them on a final basis; (2)
subsequent rates are confirmed and approved; or (3) such rates are
superseded.
Signing Authority
This document of the Department of Energy was signed on November
20, 2023, by Tracey A. LeBeau, Administrator, Western Area Power
Administration, pursuant to delegated authority from the Secretary of
Energy. That document, with the original signature and date, is
maintained by DOE. For administrative purposes only, and in compliance
with requirements of the Office of the Federal Register, the
undersigned DOE Federal Register Liaison Officer has been authorized to
sign and submit the document in electronic format for publication, as
an official document of the Department of Energy. This administrative
process in no way alters the legal effect of this document upon
publication in the Federal Register.
Signed in Washington, DC, on November 21, 2023.
Treena V. Garrett,
Federal Register Liaison Officer, U.S. Department of Energy.
Rate Schedule SLIP-F13
(Supersedes Rate Schedule SLIP-F12)
UNITED STATES DEPARTMENT OF ENERGY WESTERN AREA POWER ADMINISTRATION
Colorado River Storage Project Management Center Salt Lake City Area
Integrated Projects
Schedule of Rates for Firm Power Service (Approved Under Rate Order No.
WAPA-206)
Effective:
The first day of the first full billing period beginning on or
after January 1, 2024, and extending through December 31, 2028, or
until superseded by another rate schedule, whichever occurs earlier.
Available:
In the area served by the Salt Lake City Area Integrated Projects.
Applicable:
To the wholesale power Customer for firm power service supplied
through one meter at one point of delivery or as otherwise established
by contract.
Character:
[[Page 82887]]
Alternating current, 60 hertz, three-phase, delivered and metered
at the voltages and points established by contract.
Monthly Rate:
DEMAND CHARGE: $5.25 per kilowatt of billing demand.
ENERGY CHARGE: $12.36 mills per kilowatthour of use of Deliverable
Sales Amount (DSA) energy.
Modification of Purchase Power:
WAPA has included an amount of expense to represent the
inefficiencies of market transactions and incidental firming costs
associated with DSA energy scheduling. For more significant firming
expenses, WAPA will provide a pass-through cost option to purchase
firming power from the DSA level up to Sustainable Hydropower (SHP)
levels for requesting Customers.
Western Replacement Firming (WRF):
WRF applies to pass-through purchased power costs for energy
provided between the DSA level and SHP energy allocation. WRF is an
optional product. Customers must elect quarterly, and may elect
specific months within the quarter, to receive WRF. The charge for this
purchased power will be determined at the time of the purchase based on
market rates. There are no losses or an administrative fee charged to
WRF. A schedule for the quarterly updates is in the rate brochure on
the rate action website: <a href="http://www.wapa.gov/about-wapa/regions/crsp-2/rates/rate-order-206">www.wapa.gov/about-wapa/regions/crsp-2/rates/rate-order-206</a>.
Billing Demand:
The billing demand will be the greater of:
1. The highest 30-minute integrated demand measured during the
month up to, but not more than, the delivery obligation under the power
sales contract, or,
2. The Contract Rate of Delivery.
Billing Energy:
The billing energy will be the energy measured during the month up
to, but not more than, the delivery obligation under the power sales
contract.
Adjustment for Transformer Losses:
If delivery is made at transmission voltage but metered on the low-
voltage side of the substation, the meter readings will be increased to
compensate for transformer losses as provided in the contract.
Adjustment for Power Factor:
The Customer will be required to maintain a power factor at all
points of measurement between 95 percent lagging and 95 percent
leading.
Adjustment for Western Replacement Power (WRP):
Pursuant to the Customer's Firm Electric Service Contract, as
amended, WAPA will bill the Customer for its proportionate share of the
costs of WRP within a given time. WAPA will include in the monthly
power bill the cost of the WRP, and the incremental administrative
costs associated with WRP.
Adjustment for Customer Displacement Power (CDP) Administrative
Charges:
WAPA will include in the Customer's regular monthly power bill the
incremental administrative costs associated with CDP.
Adjustment for Minimum Power Pool:
If Lake Powell drops below ``minimum power pool'' and power cannot
be generated, WAPA will provide 30 days' notice to the Customers prior
to reducing the DSA and will work with Customers to mitigate impacts
and develop alternative solutions.
Cost Recovery Charge (CRC):
To adequately recover and maintain a sufficient balance in the
Basin Fund, WAPA uses a cost recovery mechanism, called a CRC. The CRC
is a charge on all long-term energy sales provided under WAPA's SLCA/IP
firm electric service contracts.
This charge will be, at a minimum, recalculated before July 1 of
each year, and WAPA will provide notification to the Customers
consistent with the procedures in 10 CFR 903. WAPA has the discretion
to implement the CRC at any point throughout the year using the
criteria in Table 1. The charge, if needed, will be placed into effect
on the first day of the first full billing period beginning on or after
the first day of the month the CRC is implemented. For the purposes of
the CRC, the 12-month period of a CRC will be described as a calendar
year (CY). The CRC will be calculated as follows:
Table 1--CRC Tiers
----------------------------------------------------------------------------------------------------------------
Criteria, if the Basin Fund Beginning
Tier Balance (BFBB) is: Notification
----------------------------------------------------------------------------------------------------------------
i....................................... Greater than $150 million, with an Annually (July).
expected decrease to below $75 million.
ii...................................... Less than $150 million but greater than
$120 million, with an expected 50 percent
decrease in the next CY.
iii..................................... Less than $120 million but greater than
$90 million, with an expected 40 percent
decrease in the next CY.
iv...................................... Less than $90 million but greater than $60 Semi-Annual (July/
million, with an expected 25 percent January).
decrease in the next CY.
v....................................... Less than $60 million but greater than $40 Monthly.
million with an expected decrease to
below $40 million in the next CY.
----------------------------------------------------------------------------------------------------------------
CRC sample calculations, narratives, and schedules showing the
dates for implementing a CRC throughout the year are located at the CRC
web page at: <a href="http://www.wapa.gov/about-wapa/regions/crsp-2/rates/cost-recovery-charge">www.wapa.gov/about-wapa/regions/crsp-2/rates/cost-recovery-charge</a>.
Waiver Level (WL):
WAPA will establish a WL that provides WAPA the ability to reduce
purchased power expenses by scheduling less energy than what is
contractually required. Therefore, for those Customers who voluntarily
schedule no more energy than their proportionate share of the WL, WAPA
will waive the CRC for that year. After the Funds Available have been
determined, the WL will be set at the sum of the energy that can be
provided through hydro generation and purchased with Funds Available.
The WL will not be less than the forecasted Hydro Energy.
Trigger for Water Release Criteria:
In the event that Reclamation's 24-month study projects Glen Canyon
Dam water releases will drop below 8.23 million acre feet (MAF) in a
water year (October through September), WAPA will recalculate the CRC
to include those lower estimates of hydropower generation. WAPA, as in
the yearly projection for the CRC, will give the Customers a 45-day
notice to request a waiver of the CRC if they do not want to have the
CRC charge added to their energy bills. This recalculation will remain
in effect for the remainder of the CY.
If the annual water release volumes from Glen Canyon Dam return to
8.23 MAF or higher during the trigger implementation, a new CRC will be
calculated for the next month, and the Customer will be notified.
[[Page 82888]]
Trigger for New Rate Criteria:
WAPA would reassess an implemented CRC when a new rate goes into
effect to determine if the implemented CRC should be continued,
superseded, or terminated.
Prior Year Adjustment for CRC:
Since the annual determination of the CRC is based upon estimates,
an annual, prior-year adjustment (PYA) will be calculated for those who
did not elect the waiver level. The PYA will be based on the 12-month
period the CRC was in effect.
The Customers' PYA will be based on their prior 12-months' energy
multiplied by the PYA mills/kWh to determine the dollar value that will
be assessed. The Customer will be charged or credited for this dollar
amount equally in the remaining months of the next 12-month billing
cycle. WAPA will complete this calculation within 2 months of the end
of the CRC. Therefore, if the PYA is calculated in June, the charge/
credit will be spread over the remaining 9 months of the CY (July
through March).
Adjustment for CRC Waiver:
Customers can choose not to take the full DSA energy supplied as
determined in the attached formulas for CRC and will be billed the
Energy and Capacity rates listed above, but not the CRC.
Rate Schedule SP-NW6
ATTACHMENT H to Tariff
(Supersedes Rate Schedule SP-NW5)
UNITED STATES DEPARTMENT OF ENERGY
WESTERN AREA POWER ADMINISTRATION
Colorado River Storage Project Management Center Colorado River Storage
Project
Network Integration Transmission Service (Approved Under Rate Order No.
WAPA-206)
Effective:
Rate Schedule SP-NW6 will be placed into effect on an interim basis
on the first day of the first full billing period beginning on or after
January 1, 2024, and will remain in effect until FERC confirms,
approves, and places the rate schedules into effect on a final basis
through December 31, 2028, or until the rate schedules are superseded.
Applicable:
The Transmission Customer will compensate the Colorado River
Storage Project each month for Network Integration Transmission Service
under the applicable Network Integration Transmission Service Agreement
and the formula rate described herein.
Formula Rate:
[GRAPHIC] [TIFF OMITTED] TN27NO23.003
A calculated Annual Transmission Revenue Requirement for Network
Integration Transmission Service will go into effect every October 1
based on the above formula and updated financial and operational data.
WAPA will notify the transmission customer annually of the recalculated
annual Revenue Requirement on or before September 1.
Billing:
Billing determinants for the formula rate above will be as
specified in the service agreement. Billing will occur monthly under
the formula rate.
Adjustment for Losses:
Losses incurred for service under this rate schedule will be
accounted as agreed to by the parties in accordance with the service
agreement. If losses are not fully provided by a transmission customer,
charges for financial compensation may apply.
Rate Schedule SP-PTP10
SCHEDULE 7 to Tariff
(Supersedes Schedule SP-PTP9)
UNITED STATES DEPARTMENT OF ENERGY
WESTERN AREA POWER ADMINISTRATION
Colorado River Storage Project Management Center Colorado River Storage
Project
Firm Point-to-Point Transmission Service (Approved Under Rate Order No.
WAPA-206)
Effective:
Rate Schedule SP-PTP10 will be placed into effect on an interim
basis on the first day of the first full billing period beginning on or
after January 1, 2024, and will remain in effect until FERC confirms,
approves, and places the rate schedules into effect on a final basis
through December 31, 2028, or until the rate schedules are superseded.
Applicable:
The Transmission Customer will compensate the Colorado River
Storage Project each month for Reserved Capacity under the applicable
Firm Point-To-Point Transmission Service Agreement and the formula rate
described herein.
Formula Rate:
[GRAPHIC] [TIFF OMITTED] TN27NO23.004
A recalculated rate will go into effect every October 1 based on
the above formula and updated financial and operational data. WAPA will
notify the transmission customer annually of the recalculated rate on
or before September 1. Discounts may be offered from time to time in
accordance with WAPA's Open Access Transmission Tariff.
Billing:
The formula rate above applies to the maximum amount of capacity
reserved for periods ranging from 1 hour to 1 month, payable whether
used or not. Billing will occur monthly.
[[Page 82889]]
Adjustment for Losses:
Losses incurred for service under this rate schedule will be
accounted for as agreed to by the parties in accordance with the
service agreement. If losses are not fully provided by a transmission
customer, charges for financial compensation may apply.
Rate Schedule SP-NFT9
SCHEDULE 8 to Tariff
(Supersedes Schedule SP-NFT8)
UNITED STATES DEPARTMENT OF ENERGY
WESTERN AREA POWER ADMINISTRATION
Colorado River Storage Project Management Center Colorado River Storage
Project
Non-Firm Point-to-Point Transmission Service (Approved Under Rate Order
No. WAPA-206)
Effective:
Rate Schedule SP-NFT9 will be placed into effect on an interim
basis on the first day of the first full billing period beginning on or
after January 1, 2024, and will remain in effect until FERC confirms,
approves, and places the rate schedules into effect on a final basis
through December 31, 2028, or until the rate schedules are superseded.
Applicable:
The Transmission Customer will compensate the Colorado River
Storage Project each month for Non-Firm, Point-to-Point Transmission
Service under the applicable Non-Firm, Point-to-Point Transmission
Service Agreement and the formula rate described herein.
Formula Rate:
[GRAPHIC] [TIFF OMITTED] TN27NO23.005
A recalculated rate will go into effect every October 1 based on
the above formula and updated financial and load data. WAPA will notify
the transmission customer annually of the recalculated rate on or
before September 1. Discounts may be offered from time-to-time in
accordance with WAPA's Open Access Transmission Tariff.
Billing:
The formula rate above applies to the maximum amount of capacity
reserved for periods ranging from 1 hour to 1 month, payable whether
used or not. Billing will occur monthly.
Adjustment for Losses:
Power and energy losses incurred in connection with the
transmission and delivery of power and energy under this rate schedule
shall be supplied by the customer in accordance with the service
contract. If losses are not fully provided by a transmission customer,
charges for financial compensation may apply.
Rate Schedule SP-UU3
SCHEDULE 10 to Tariff
(Supersedes Schedule SP-UU2)
UNITED STATES DEPARTMENT OF ENERGY
WESTERN AREA POWER ADMINISTRATION
Colorado River Storage Project Management Center Colorado River Storage
Project
Unreserved Use Penalties (Approved Under Rate Order No. WAPA-206)
Effective:
Rate Schedule SP-UU3 will be placed into effect on an interim basis
on the first day of the first full billing period beginning on or after
January 1, 2024, and will remain in effect until FERC confirms,
approves, and places the rate schedules into effect on a final basis
through December 31, 2028, or until the rate schedules are superseded.
Applicable:
The Transmission Customer shall compensate the Colorado River
Storage Project (CRSP) each month for any unreserved use of the
transmission system (Unreserved Use) under the applicable transmission
service rates as outlined herein. Unreserved Use occurs when an
eligible customer uses transmission service that it has not reserved or
a transmission customer uses transmission service in excess of its
reserved capacity. Unreserved Use may also include a customer's failure
to curtail transmission when requested.
Penalty Rate:
The penalty rate for a Transmission Customer that engages in
Unreserved Use is 200 percent of CRSP's approved transmission service
rate for point-to-point (SP-PTP9) transmission service assessed as
follows:
(i) The Unreserved Use Penalty for a single hour of Unreserved Use
is based upon the rate for daily firm PTP service.
(ii) The Unreserved Use Penalty for more than one assessment for a
given duration (e.g., daily) increases to the next longest duration
(e.g., weekly).
(iii) The Unreserved Use Penalty for multiple instances of
Unreserved Use (e.g., more than 1 hour) within a day is based on the
rate for daily firm PTP service. The Unreserved Use Penalty charge for
multiple instances of Unreserved Use isolated to 1 calendar week would
result in a penalty based on the rate for weekly firm PTP service. The
Unreserved Use Penalty charge for multiple instances of Unreserved Use
during more than 1 week in a calendar month will be based on the rate
for monthly firm PTP service.
A Transmission Customer that exceeds its firm reserved capacity at
any point of receipt or point of delivery or an eligible customer that
uses transmission service at a point of receipt or point of delivery
that it has not reserved is required to pay for all ancillary services
identified in WAPA's Open Access Transmission Tariff that were provided
by the CRSP and associated with the Unreserved Use. The Transmission
Customer will pay for ancillary services based on the amount of
transmission service it used and did not reserve.
Rate:
The rate for Unreserved Use Penalties is 200 percent of WAPA's
approved rate for firm point-to-point transmission service assessed as
described above. Any change to the rate for Unreserved Use Penalties
will be listed in a revision to this rate schedule issued under
applicable Federal laws and policies and made part of the applicable
service agreement.
Rate Schedule SP-EI6
SCHEDULES 4 & 9 to Tariff
(Supersedes Rate Schedule SP-EI5)
UNITED STATES DEPARTMENT OF ENERGY WESTERN AREA POWER ADMINISTRATION
Colorado River Storage Project Management Center Colorado River Storage
Project
Energy and Generator Imbalance Services (Approved Under Rate Order No.
WAPA-206)
Effective:
Rate Schedule SP-EI6 will be placed into effect on an interim basis
on the first day of the first full billing period beginning on or after
January 1, 2024, and will remain in effect until FERC confirms,
approves, and places the rate schedules into effect on a final basis
[[Page 82890]]
through December 31, 2028, or until the rate schedules are superseded.
Applicable:
To all CRSP Transmission Customers receiving this service.
Formula Rates:
Provided through the Western Area Colorado Missouri (WACM)
Balancing Authority under Rate Schedules L-AS4 and L-AS9, or as
superseded.
Rate Schedule SP-SSR6
SCHEDULES 5 & 6 to Tariff
(Supersedes Rate Schedule SP-SSR5)
UNITED STATES DEPARTMENT OF ENERGY WESTERN AREA POWER ADMINISTRATION
Colorado River Storage Project Management Center Colorado River Storage
Project
Operating Reserves--Spinning and Supplemental Reserve Services
(Approved Under Rate Order No. WAPA-206)
Effective:
Rate Schedule SP-SSR5 will be placed into effect on an interim
basis on the first day of the first full billing period beginning on or
after January 1, 2024, and will remain in effect until FERC confirms,
approves, and places the rate schedules into effect on a final basis
through December 31, 2028, or until the rate schedules are superseded.
Applicable:
To all CRSP Transmission Customers receiving this service.
Formula Rate:
The Transmission Customer serving loads within the transmission
provider's balancing authority must acquire Spinning and Supplemental
Reserve services from CRSP, from a third party, or by self-supply.
Rate Schedule SP-SS2
(Supersedes Rate Schedule SP-SS1)
UNITED STATES DEPARTMENT OF ENERGY WESTERN AREA POWER ADMINISTRATION
Colorado River Storage Project Management Center Colorado River Storage
Project
Sale of Surplus Products (Approved Under Rate Order No. WAPA-206)
Effective:
The first day of the first full billing period beginning on or
after January 1, 2024, and extending through December 31, 2028, or
until superseded by another rate schedule, whichever occurs earlier.
Applicable:
This Rate Schedule applies to the sale of the following Salt Lake
City Area Integrated Projects (SLCA/IP) surplus energy and capacity
products: energy, frequency response, regulation, and reserves. If any
of the above SLCA/IP surplus products are available, SLCA/IP can make
the product(s) available for sale, providing entities enter into
separate agreement(s) with CRSP Marketing which will specify the terms
of the sale(s).
Formula Rate:
The charge for each product will be determined at the time of the
sale based on market rates, plus administrative costs. The customer
will be responsible for acquiring transmission service necessary to
deliver the product(s), for which a separate charge may be incurred.
Rate Schedule SP-NFJDT
SCHEDULE 8R to OATT Attachment
(Supersedes Rate Schedule SP-NFJDT dated
October 1, 2021, through September 30, 2024)
UNITED STATES DEPARTMENT OF ENERGY WESTERN AREA POWER ADMINISTRATION
Colorado River Storage Project Management Center Colorado River Storage
Project
Joint Dispatch Transmission Service (Approved Under Rate Order No.
WAPA-206)
Effective:
The first day of the first full billing period beginning on or
after January 1, 2024, and extending through December 31, 2028, or
until superseded by another rate schedule, whichever occurs earlier.
Applicable:
This rate schedule applies to the Colorado River Storage Project
(CRSP) as the Transmission Service Provider (TSP) when the Colorado
River Storage Project Management Center is participating in the Western
Energy Imbalance Service (WEIS) Market. The Joint Dispatch Transmission
Service (JDTS) Customer shall compensate the CRSP TSP for JDTS
commensurate with the receipt or delivery of energy dispatched for the
JDTS Customer pursuant to the WEIS Tariff under the formula rate
described herein.
Formula Rate:
Hourly delivery:
On-Peak Hours: the on-peak charge $0.00/MWh
Off-Peak Hours: the off-peak charge $0.00/MWh
[FR Doc. 2023-26049 Filed 11-24-23; 8:45 am]
BILLING CODE 6450-01-P
</pre><script data-cfasync="false" src="/cdn-cgi/scripts/5c5dd728/cloudflare-static/email-decode.min.js"></script></body>
</html>Indexed from Federal Register on November 27, 2023.
This is legal information, not legal advice. Laws vary by jurisdiction and change frequently. Always verify current law with official sources and consult a licensed attorney in your jurisdiction for advice on your specific situation.