Notice2025-17842
Notice of Interim Approval of Rate Schedules for Kerr-Philpott System of Projects
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
September 16, 2025
Effective
October 1, 2025
Issuing agencies
Energy DepartmentSoutheastern Power Administration
Abstract
The Administrator for the Southeastern Power Administration (Southeastern) has confirmed and approved, on an interim basis, rate schedules VA-1-E, VA-2-E, VA-3-E, VA-4-E, DEP-1-E, DEP-2-E, DEP-3-E, DEP-4-E, AP-1-E, AP-2-E, AP-3-E, AP-4-E, NC-1-E, and Replacement-2-D. These rate schedules are applicable to Southeastern power sold to existing preference customers in North Carolina and Virginia. The rate schedules are approved on an interim basis through September 30, 2030, and are subject to confirmation and approval by the Federal Energy Regulatory Commission (FERC) on a final basis.
Full Text
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<title>Federal Register, Volume 90 Issue 177 (Tuesday, September 16, 2025)</title>
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[Federal Register Volume 90, Number 177 (Tuesday, September 16, 2025)]
[Notices]
[Pages 44665-44682]
From the Federal Register Online via the Government Publishing Office [<a href="http://www.gpo.gov">www.gpo.gov</a>]
[FR Doc No: 2025-17842]
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DEPARTMENT OF ENERGY
Southeastern Power Administration
Notice of Interim Approval of Rate Schedules for Kerr-Philpott
System of Projects
AGENCY: Southeastern Power Administration, DOE.
ACTION: Notice of interim approval.
-----------------------------------------------------------------------
SUMMARY: The Administrator for the Southeastern Power Administration
(Southeastern) has confirmed and approved, on an interim basis, rate
schedules VA-1-E, VA-2-E, VA-3-E, VA-4-E, DEP-1-E, DEP-2-E, DEP-3-E,
DEP-4-E, AP-1-E, AP-2-E, AP-3-E, AP-4-E, NC-1-E, and Replacement-2-D.
These rate schedules are applicable to Southeastern power sold to
existing preference customers in North Carolina and Virginia. The rate
schedules are approved on an interim basis through September 30, 2030,
and are subject to confirmation and approval by the Federal Energy
Regulatory Commission (FERC) on a final basis.
DATES: Approval of rates on an interim basis is effective on October 1,
2025.
FOR FURTHER INFORMATION CONTACT: Carter B. Edge, Assistant
Administrator for Finance and Marketing, Southeastern Power
Administration, Department of Energy, 1166 Athens Tech Road, Elberton,
Georgia 30635-6711, (706) 213-3800; Email: <a href="/cdn-cgi/l/email-protection#e3a08291978691cda6878486a390869382cd878c86cd848c95"><span class="__cf_email__" data-cfemail="410220333524336f0425262401322431206f252e246f262e37">[email protected]</span></a>.
SUPPLEMENTARY INFORMATION: FERC, by Order issued December 11, 2020, in
Docket No. EF20-5-000 (Accession No.: 20201211-3017), confirmed and
approved Wholesale Power Rate Schedules VA-1-D, VA-2-D, VA-3-D, VA-4-D,
DEP-1-D, DEP-2-D, DEP-3-D, DEP-4-D, AP-1-D, AP-2-D, AP-3-D, AP-4-D, NC-
1-D, and Replacement-2-C for the period October 1, 2020, through
September 30, 2025. This order replaces these rate schedules on an
interim basis, subject to final approval by FERC.
Department of Energy
Administrator, Southeastern Power Administration
In the Matter of: Southeastern Power Administration, Kerr-Philpott
System Power Rates, Rate Order No. SEPA-67
Order Confirming and Approving Power Rates on an Interim Basis
Rate Order No. SEPA-67 and associated rate schedules are applicable
to Southeastern Power Administration (Southeastern) power sold to
existing preference customers in North Carolina and Virginia. The rate
schedules are approved on an interim basis, effective October 1, 2025,
through September 30, 2030, and are subject to confirmation and
approval by the Federal Energy Regulatory Commission (FERC) on a final
basis.
Background
Power from the Kerr-Philpott System is presently sold under
Wholesale Power Rate Schedules VA-1-D, VA-2-D, VA-3-D, VA-4-D, DEP-1-D,
DEP-2-D, DEP-3-D, DEP-4-D, AP-1-D, AP-2-D, AP-3-D, AP-4-D, NC-1-D, and
Replacement-2-C. These rate schedules were approved by the FERC in
Docket No. EF20-5-000 on December 11, 2020, for a period ending
September 30, 2025 (Accession No.: 20201211-3017).
Public Notice and Comment
Notice of a proposed rate adjustment and an adjustment to the
annual true-up mechanism was published in the Federal Register May 15,
2025 (90 FR 20669). Southeastern proposed an increase to existing rate
schedules and updating the annual true-up mechanism to keep the true-up
rates, during over-recovery periods, from being reduced below the
initial base capacity and energy rate set in rate filings, for the sale
of power from the Kerr-Philpott System effective October 1, 2025,
through September 30, 2030. The notice advised interested parties of a
public information and comment forum to be
[[Page 44666]]
held in Elberton, Georgia, and virtually by Microsoft Teams, on June
17, 2025. Written comments were accepted through August 13, 2025. The
revenue requirement proposed at the forum was $43,000,000 per year. The
initial base rates proposed were $5.95 per kilowatt per month for
capacity and 22.75 mills per kilowatt-hour for energy. The rates are
based on a repayment study estimating the Kerr-Philpott System will
produce the following net revenue available for repayment (rounded to
the nearest $10,000):
------------------------------------------------------------------------
Estimated annual Cumulative net
net revenue revenue
Fiscal year available for available for
repayment repayment
------------------------------------------------------------------------
2025.............................. $1,840,000 $1,840,000
2026.............................. 170,000 2,010,000
2027.............................. 3,530,000 5,540,000
2028.............................. 3,840,000 9,380,000
2029.............................. 3,930,000 13,310,000
2030.............................. 3,440,000 16,750,000
2031.............................. 3,600,000 20,350,000
2032.............................. 3,720,000 24,070,000
2033.............................. 3,860,000 27,930,000
2034.............................. 4,020,000 31,950,000
------------------------------------------------------------------------
The proposed rate schedules continue adjustments annually on April
1 of each year, based on the variance of the actual cumulative net
revenue available for repayment from the planned cumulative net revenue
available for repayment and include the updated mechanism for over-
recovery periods. The annual adjustment will be, for every $100,000
under-recovery of the planned cumulative net revenue available for
repayment, Southeastern will increase the base capacity charge by $0.02
per kilowatt per month, up to a maximum of $0.75 per kilowatt per
month, and increase the base energy charge by 0.10 mills per kilowatt-
hour, up to a maximum of 3.0 mills per kilowatt per hour, to be
implemented April 1 of the next fiscal year. For every $100,000 over-
recovery of the planned cumulative net revenue available for repayment,
Southeastern will reduce the current base capacity charge by $0.02 per
kilowatt per month, up to a maximum of $0.75 per kilowatt per month but
not below the initial base capacity charge set in the rate filing, and
reduce the current base energy charge by 0.10 mills per kilowatt-hour,
up to a maximum of 3.0 mills per kilowatt-hour but not below the
initial base energy charge set in the rate filing, to be implemented
April 1 of the next fiscal year. Southeastern will give written notice
to the customers of the amount of the true-up to the capacity and
energy rates by February 1 of the next fiscal year.
Public Comments
Southeastern received oral comments from one participant as part of
the public information and comment forum on June 17, 2025. Southeastern
received written comments mirroring the oral comments provided in the
public information and comment forum from the same representing
organization as the forum participant.
The comments are summarized below. Southeastern's responses are
provided.
Comment 1: The SeFPC has concerns that the proposed rate increase
has not implemented appropriate rate reductions which would otherwise
be proper pursuant to the Administrator's authority under Section 5 of
the Flood Control Act of 1944. In particular, we believe that SEPA has
not reduced proposed costs related to dam safety repairs.
Response to Comment 1: Southeastern's Administrator agrees
protecting hydropower customers from bearing costs unrelated to
hydropower is a priority, and other such costs should be properly
attributed to the relevant purposes of the projects. Southeastern
retains authority to ensure rates for power will be the lowest possible
rates consistent with sound business principles within the meaning of
Section 5 of the Flood Control Act of 1944. While SEPA's Administrator
has the responsibility to determine which costs are appropriate, the
Administrator is obligated to prudently follow sound business
principles in recovering costs associated with generating hydropower,
including the amortization of capital Federal investment allocated to
power. Southeastern will continue coordination efforts to work with the
US Army Corps of Engineers (Corps) to ensure appropriate charging
practices.
Comment 2: In the proposed rate increase, supporting materials
indicate SEPA will recover $2,050,000 for capitalized expense related
to the switchgear building. This is a direct expense for hydropower
which was funded through the customer funding program supported by
SeFPC members. However, the replacement of the switchgear building is a
direct result of the landslide or seismic change at the Philpott
project. As such the recovery of the expense should be limited as
prescribed by the Dam Safety Act.
Response to Comment 2: Southeastern's Administrator agrees Section
1203 of WRDA 1986 (33 U.S.C. 467n(a)) provides special cost-sharing for
modification of dams and related facilities constructed or operated by
the Corps, the cause of which results from new hydrologic or seismic
data or changes in state-of-the-art design or construction criteria
deemed necessary for safety purposes. However, the capitalized expense
of the switchgear building, funded through the customer funding
program, is appropriate to include in the proposed rates. The expense
of the new switchgear building is appropriate as a direct replacement
of an existing asset, without upgrades or changes to building function
or seismic requirements, ensuring continuity of service rather than
enhancement. Replacement of the switchgear building and damaged
equipment is not due to a design or construction deficiency but instead
due to an external force (i.e., landslide). As a self-insured entity,
the Federal government assumes direct financial responsibility for
incidents of this nature.
Comment 3: Similarly, as the proposed rate models recovery of the
Philpott rewind at a cost of $28,825,400, certain of those costs should
be reduced because the Corps estimate for the entire rewind includes
costs caused by the landslide. Specifically, the Corps has stated to
the Customers that delays caused by the landslide have led to cost
increases. As such, the total cost of the Philpott rewind should be
decreased in light of the cost impacts solely related to the landslide.
Moreover, because the Corps has informed the Customers' representatives
that the project will not be completed until 2027 using appropriated
dollars, further modeling may be needed to ensure that the customers
taking service under the proposed rate are repaying the investment on
the project no sooner than when the project becomes commercially
operable. In this context, we anticipate that the rate starts to
collect interest associated with the capital expenditure for the rewind
starting in 2026. Given that the Corps has predicted that the project
will be completed in the fall of 2027, the proposed rate over collects
for both capital and interest.
Response to Comment 3: Southeastern's Administrator agrees Section
1203 of WRDA 1986 (33 U.S.C. 467n(a)) provides special cost-sharing for
modification of dams and related facilities constructed or operated by
the Corps, the cause of which results from new hydrologic or seismic
data or changes in state-of-the-art design or construction criteria
deemed necessary for safety purposes. However, the cost of the Philpott
rewind, including interest, is an appropriate cost to include in the
proposed rates. The delays and cost impacts are not due to new
hydrologic or seismic data or changes in state-of-
[[Page 44667]]
the-art design or construction criteria deemed necessary for safety
purposes but rather an external force (i.e., landslide). 18 CFR
300.12(b) specifies what must be included in the revenue recovery
study. The placed-in-service date of Fiscal Year 2026 was based on best
available projection data provided to Southeastern by the Corps at the
time the revised study was conducted. The payable to U.S. Treasury in
each of the generating projects is to be repaid to the U.S. Treasury
within the service lives of the assets, not to exceed 50 years from the
time the facility is placed in service. There is no requirement for
repayment of a specific amount on an annual basis. Interest during
construction costs are held by the Corps in Construction in Progress
until the asset is transferred to Plant in Service (PIS). At that time,
the applicable portion of the interest, together with the other costs
representing the completed asset, will be transferred to the
appropriate PIS accounts and will be picked up by Southeastern as a
capitalized addition or replacement. Interest on Investment begins
accruing when the investment is recognized for repayment and is an
annual expense.
Comment 4: As noted by counsel at the public forum, we have
concerns regarding the inclusion of costs related to water supply which
are modeled for inclusion in the rate. All water supply operations
under the Water Supply Act of 1958 are assigned an appropriate share of
operations and maintenance costs. Asking hydropower customers to assume
a portion of water supply costs over collects costs which by law should
otherwise be directly assigned to the water supply beneficiaries. As
such, SEPA should exclude such costs from the proposed rate.
Response to Comment 4: Southeastern's Administrator agrees
protecting hydropower customers from bearing costs unrelated to
hydropower is a priority. The water supply expenses for Kerr and
Philpott are considered to be joint costs by the Corps and therefore,
Southeastern picked up the joint percentage in O&M for power.
In 2018, the Corps financial statements were restated to align with
the final cost allocation studies regarding O&M expenses. After the
restatement, water supply revenue began being reported on the income
statement of John H. Kerr project's financial statements under ``Water
Supply'', with no credit to power. Southeastern, like other PMAs, is
tasked with repaying the power investment, including interest, through
revenues generated through the sale of power. The water supply revenue
is combined with power revenues to repay the power investment.
Southeastern records the water supply revenue as ``other operating
revenue'' when developing the consolidated financial statement because
this revenue is associated with a re-allocation of storage from
hydropower. Southeastern will continue coordination efforts to work
with the Corps to ensure appropriate charging practices.
Discussion
System Repayment
Subsequent to the Public Information and Comment Forum held on June
17, 2025. A formula error within the study was noticed omitting a
capitalized deficit from Fiscal Year 2025's end of year remaining
investment. The formula error was corrected and the rates proposed
during the forum remained unaffected. However, the formula correction
did affect the planned cumulative net revenue available for repayment
located in the rate schedules and used in the annual adjustment
computation.
Additionally, Southeastern received Fiscal Year 2018 through Fiscal
Year 2024 revised Multi-Purpose Pension and Post-Retirement Benefit
reports from the Corps on August 12, 2025. The revised reports are
currently unaudited. However, Southeastern has confidence the revised
pension and post-retirement benefit projections are appropriate and
conducted an updated revised repayment study reflecting corrected
pension and post-retirement benefit expense projections. Using initial
proposed rates, the revenue recovery study indicated an over-recovery
of revenue. The amended revised repayment study indicated an
approximate 2.33% reduction in the annual revenue requirement compared
to the originally proposed annual revenue requirement that could be
achieved. An amended revised annual revenue requirement of $42,000,000
will meet cost recovery and repayment criteria. The amended revised
initial base rates are $5.71 per kilowatt per month for capacity and
21.83 mills per kilowatt-hour for energy. The rates are based on a
repayment study estimating the Kerr-Philpott System will produce the
following net revenue available for repayment (rounded to the nearest
$10,000):
------------------------------------------------------------------------
Estimated annual Cumulative net
net revenue revenue
Fiscal year available for available for
repayment repayment
------------------------------------------------------------------------
2025.............................. $360,000 $360,000
2026.............................. 630,000 990,000
2027.............................. 4,000,000 4,990,000
2028.............................. 4,310,000 9,300,000
2029.............................. 4,460,000 13,760,000
2030.............................. 3,970,000 17,730,000
2031.............................. 4,150,000 21,880,000
2032.............................. 4,280,000 26,160,000
2033.............................. 4,430,000 30,590,000
2034.............................. 4,610,000 35,200,000
------------------------------------------------------------------------
An examination of Southeastern's amended revised power repayment
study, for the Kerr-Philpott System shows with the amended revised
initial base rates, all system power costs are paid within the
appropriate repayment period and meet the cost recovery criteria
required by existing law and DOE Order RA 6120.2. The Administrator,
Southeastern Power Administration, has certified the rates are
consistent with applicable law and they are the lowest possible rates
to customers consistent with sound business principles.
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 Southeastern's Administrator; (2) the
authority to confirm, approve, and place such rates into effect on an
interim basis to the Deputy Secretary of Energy; and (3) the authority
to confirm, approve, and place into effect on a final basis, or to
remand or disapprove such rates, to FERC. By Delegation Order No. S1-
DEL-S3-2024, effective August 30, 2024, the Secretary of Energy also
delegated the authority to confirm, approve, and place such rates into
effect on an interim basis to the Under Secretary for Infrastructure.
By Redelegation Order No. S3-DEL-SEPA-2023, effective April 10, 2023,
the Under Secretary for Infrastructure redelegated the authority to
confirm, approve, and place such rates into effect on an interim basis
to the Administrator, Southeastern Power Administration.
Environmental Compliance
Southeastern has determined that this action fits within the
following categorical exclusion listed in appendix B of 10 CFR part
1021 and Appendix B of DOE's NEPA implementing procedures published on
June 30, 2025: 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. A copy of the categorical exclusion
determination is available on
[[Page 44668]]
Southeastern's website at <a href="https://bit.ly/KerrPhilpottCategoricalExclusion">https://bit.ly/KerrPhilpottCategoricalExclusion</a>.
Determination Under Executive Order 12866
Southeastern 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.
Availability of Information
Information regarding these rates, including studies, and other
supporting materials, is available for public review in the offices of
Southeastern Power Administration, 1166 Athens Tech Road, Elberton,
Georgia 30635-6711.
Order
In view of the foregoing and pursuant to the authority redelegated
to me by the Under Secretary for Infrastructure, I hereby confirm and
approve on an interim basis, effective October 1, 2025, attached
Wholesale Power Rate Schedules VA-1-E, VA-2-E, VA-3-E, VA-4-E, DEP-1-E,
DEP-2-E, DEP-3-E, DEP-4-E, AP-1-E, AP-2-E, AP-3-E, AP-4-E, NC-1-E, and
Replacement-2-D. The rate schedules shall remain in effect on an
interim basis through September 30, 2030, unless such period is
extended or until FERC confirms and approves them or substitute rate
schedules on a final basis.
Signing Authority
This document of the Department of Energy was signed on September
11, 2025, by Virgil G. Hobbs III, Administrator for Southeastern 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 September 12, 2025.
Treena V. Garrett,
Federal Register Liaison Officer, U.S. Department of Energy.
Wholesale Power Rate Schedule VA-1-E
Availability: This rate schedule shall be available to public
bodies and cooperatives (any one of whom is hereinafter called the
Customer) in Virginia and North Carolina to whom power may be
transmitted and scheduled pursuant to contracts between the Government,
Virginia Electric and Power Company (hereinafter called the Company),
the Company's Transmission Operator, currently PJM Interconnection LLC
(hereinafter called PJM), and the Customer. This rate schedule is
applicable to customers receiving power from the Government on an
arrangement where the Company schedules the power and provides the
Customer a credit on their bill for Government power. Nothing in this
rate schedule shall preclude modifications to the aforementioned
contracts to allow an eligible customer to elect service under another
rate schedule.
Applicability: This rate schedule shall be applicable to the sale
at wholesale of power and accompanying energy generated at the John H.
Kerr and Philpott Projects and sold under appropriate contracts between
the Government and the Customer.
Character of Service: The electric capacity and energy supplied
hereunder will be delivered at the delivery points of the Customer on
the Company's transmission and distribution system.
Monthly Rate: The initial base monthly rate for capacity, energy,
and generation services provided under this rate schedule for the
period specified shall be:
Initial Base Capacity Charge: $5.71 per kilowatt of total contract
demand per month.
Initial Base Energy Charge: 21.83 mills per kilowatt-hour.
The rates are based on a repayment study that projects that the
Kerr-Philpott System will produce the following net revenue available
for repayment by fiscal year and cumulative net revenue available for
repayment by fiscal year:
------------------------------------------------------------------------
Estimated annual Cumulative net
net revenue revenue
Fiscal year available for available for
repayment repayment
------------------------------------------------------------------------
2025.............................. $360,000 $360,000
2026.............................. 630,000 990,000
2027.............................. 4,000,000 4,990,000
2028.............................. 4,310,000 9,300,000
2029.............................. 4,460,000 13,760,000
2030.............................. 3,970,000 17,730,000
2031.............................. 4,150,000 21,880,000
2032.............................. 4,280,000 26,160,000
2033.............................. 4,430,000 30,590,000
2034.............................. 4,610,000 35,200,000
------------------------------------------------------------------------
The rates include a true-up of the capacity and energy rates based
on the variance of the actual cumulative net revenue available for
repayment from the planned cumulative net revenue available for
repayment in the table above. For every $100,000 under-recovery of the
planned cumulative net revenue available for repayment, Southeastern
will increase the base capacity charge by $0.02 per kilowatt per month,
up to a maximum of $0.75 per kilowatt per month, and increase the base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt per hour, to be implemented April 1 of the next
fiscal year. For every $100,000 over-recovery of the planned cumulative
net revenue available for repayment, Southeastern will reduce the
current base capacity charge by $0.02 per kilowatt per month, up to a
maximum of $0.75 per kilowatt per month but not below the initial base
capacity charge set in the rate filing, and reduce the current base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt-hour but not below the initial base energy charge
set in the rate filing, to be implemented April 1 of the next fiscal
year. Southeastern will give written notice to the customers of the
amount of the true-up to the capacity and energy rates by February 1 of
the next fiscal year.
Additional rates for transmission and any ancillary services
provided under this rate schedule shall be the rates charged
Southeastern Power Administration by the Company or PJM. Future
adjustments to these rates will become effective upon acceptance for
filing by the Federal Energy Regulatory Commission (FERC) of the
Company's rate.
Transmission: $7.53 per kilowatt of total contract demand per month
estimated as of March 2025, is presented for illustrative purposes.
Ancillary Services: 8.24 mills per kilowatt-hour of energy
estimated as of March 2025, is presented for illustrative purposes.
The initial charge for transmission and Ancillary Services will be
the Customer's ratable share of the charges for transmission,
distribution, and ancillary services paid by the Government. The
charges for transmission and ancillary services are governed by and
subject to refund based upon the determination in proceedings before
FERC involving the Company's or PJM's Open Access Transmission Tariff
(OATT).
Proceedings before FERC involving the OATT or the Distribution
charge may result in the separation of charges currently included in
the transmission rate. In this event, the Government may charge the
Customer for any and all separate transmission, ancillary services, and
distribution charges paid by the Government in behalf of the
[[Page 44669]]
Customer. These charges could be recovered through a capacity charge or
an energy charge, as determined by the Government.
Tandem Transmission Charge: $3.33 per kilowatt of total contract
demand per month, as an estimated cost as of March 2025.
The tandem transmission charge will recover the cost of
transmitting power from a project to the border of another transmitting
system. This rate will be a formulary rate based on the cost to the
Government for transmission of power from the Philpott project to the
border of the Virginia Electric and Power Company System and the cost
to the Government for transmission of power from the John H. Kerr
Project to the border of the Duke Energy Progress System. These charges
could be recovered through a capacity charge or an energy charge, as
determined by the Government.
Transmission and Ancillary Services: The charges for transmission
and ancillary services shall be governed by and subject to refund based
upon the determination in the proceeding involving the Company's or
PJM's OATT.
Capacity Performance Non-Performance Charge: Requirements of the
PJM capacity performance market may lead to non-performance charges to
Southeastern. These non-performance charges, if incurred, will be
allocated to the capacity delivered in PJM (currently 120,100
kilowatts) in the month incurred.
Contract Demand: The contract demand is the amount of capacity in
kilowatts stated in the contract which the Government is obligated to
supply and the Customer is entitled to receive.
Energy to be Furnished by the Government: The Government will sell
to the Customer and the Customer will purchase from the Government
energy each billing month equivalent to a percentage specified by
contract of the energy made available to the Company (less applicable
losses). The Customer's contract demand and accompanying energy will be
allocated proportionately to its individual delivery points served from
the Company's system. The applicable energy loss factor for
transmission is specified in the OATT.
These losses shall be effective until modified by FERC, pursuant to
application by the Company or PJM under Section 205 of the Federal
Power Act or Southeastern Power Administration under Section 206 of the
Federal Power Act or otherwise.
Billing Month: The billing month for power sold under this schedule
shall end at 12:00 midnight on the last day of each calendar month.
Wholesale Power Rate Schedule VA-2-E
Availability: This rate schedule shall be available to public
bodies and cooperatives (any one of whom is hereinafter called the
Customer) in Virginia and North Carolina to whom power may be
transmitted pursuant to contracts between the Government, Virginia
Electric and Power Company (hereinafter called the Company), the
Company's Transmission Operator, currently PJM Interconnection LLC
(hereinafter called PJM), and the Customer. The Customer has chosen to
self-schedule and does not receive Government power under an
arrangement where the Company schedules the power and provides a credit
on the Customer's bill for Government power. The Customer is
responsible for providing a scheduling arrangement with the Government.
The Government is responsible for arranging transmission with the
Company and PJM. Nothing in this rate schedule shall preclude
modifications to the aforementioned contracts to allow an eligible
customer to elect service under another rate schedule.
Applicability: This rate schedule shall be applicable to the sale
at wholesale of power and accompanying energy generated at the John H.
Kerr and Philpott Projects and sold under appropriate contracts between
the Government and the Customer.
Character of Service: The electric capacity and energy supplied
hereunder will be delivered at the delivery points of the Customer on
the Company's transmission and distribution system.
Monthly Rate: The initial base monthly rate for capacity, energy,
and generation services provided under this rate schedule for the
period specified shall be:
Initial Base Capacity Charge: $5.71 per kilowatt of total contract
demand per month.
Initial Base Energy Charge: 21.83 mills per kilowatt-hour.
The rates are based on a repayment study that projects that the
Kerr-Philpott System will produce the following net revenue available
for repayment by fiscal year and cumulative net revenue available for
repayment by fiscal year:
------------------------------------------------------------------------
Estimated annual Cumulative net
net revenue revenue
Fiscal year available for available for
repayment repayment
------------------------------------------------------------------------
2025.............................. $360,000 $360,000
2026.............................. 630,000 990,000
2027.............................. 4,000,000 4,990,000
2028.............................. 4,310,000 9,300,000
2029.............................. 4,460,000 13,760,000
2030.............................. 3,970,000 17,730,000
2031.............................. 4,150,000 21,880,000
2032.............................. 4,280,000 26,160,000
2033.............................. 4,430,000 30,590,000
2034.............................. 4,610,000 35,200,000
------------------------------------------------------------------------
The rates include a true-up of the capacity and energy rates based
on the variance of the actual cumulative net revenue available for
repayment from the planned cumulative net revenue available for
repayment in the table above. For every $100,000 under-recovery of the
planned cumulative net revenue available for repayment, Southeastern
will increase the base capacity charge by $0.02 per kilowatt per month,
up to a maximum of $0.75 per kilowatt per month, and increase the base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt per hour, to be implemented April 1 of the next
fiscal year. For every $100,000 over-recovery of the planned cumulative
net revenue available for repayment, Southeastern will reduce the
current base capacity charge by $0.02 per kilowatt per month, up to a
maximum of $0.75 per kilowatt per month but not below the initial base
capacity charge set in the rate filing, and reduce the current base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt-hour but not below the initial base energy charge
set in the rate filing, to be implemented April 1 of the next fiscal
year. Southeastern will give written notice to the customers of the
amount of the true-up to the capacity and energy rates by February 1 of
the next fiscal year.
Additional rates for transmission and any ancillary services
provided under this rate schedule shall be the rates charged
Southeastern Power Administration by the Company or PJM. Future
adjustments to these rates will become effective upon acceptance for
filing by the Federal Energy Regulatory Commission (FERC) of the
Company's rate.
Transmission: $7.53 per kilowatt of total contract demand per month
estimated as of March 2025, is presented for illustrative purposes.
Ancillary Services: 8.24 mills per kilowatt-hour of energy
estimated as of March 2025, is presented for illustrative purposes.
The initial charge for transmission and ancillary services will be
the Customer's ratable share of the charges for transmission,
distribution, and ancillary services paid by the
[[Page 44670]]
Government. The charges for transmission and ancillary services are
governed by and subject to refund based upon the determination in
proceedings before FERC involving the Company's or PJM's Open Access
Transmission Tariff (OATT).
Proceedings before FERC involving the OATT or the distribution
charge may result in the separation of charges currently included in
the transmission rate. In this event, the Government may charge the
Customer for any and all separate transmission, ancillary services, and
distribution charges paid by the Government in behalf of the Customer.
These charges could be recovered through a capacity charge or an energy
charge, as determined by the Government.
Tandem Transmission Charge: $3.33 per kilowatt of total contract
demand per month, as an estimated cost as of March 2025.
The tandem transmission charge will recover the cost of
transmitting power from a project to the border of another transmitting
system. This rate will be a formulary rate based on the cost to the
Government for transmission of power from the Philpott project to the
border of the Virginia Electric and Power Company System and the cost
to the Government for transmission of power from the John H. Kerr
Project to the border of the Duke Energy Progress System. These charges
could be recovered through a capacity charge or an energy charge, as
determined by the Government.
Transmission and Ancillary Services: The charges for transmission
and ancillary services shall be governed by and subject to refund based
upon the determination in the proceeding involving the Company's or
PJM's OATT.
Capacity Performance Non-Performance Charge: Requirements of the
PJM capacity performance market may lead to non-performance charges to
Southeastern. These non-performance charges, if incurred, will be
allocated to the capacity delivered in PJM (currently 120,100
kilowatts) in the month incurred.
Contract Demand: The contract demand is the amount of capacity in
kilowatts stated in the contract which the Government is obligated to
supply and the Customer is entitled to receive.
Energy to be Furnished by the Government: The Government will sell
to the Customer and the Customer will purchase from the Government
energy each billing month equivalent to a percentage specified by
contract of the energy made available to the Company (less applicable
losses). The Customer's contract demand and accompanying energy will be
allocated proportionately to its individual delivery points served from
the Company's system. The applicable energy loss factor for
transmission is specified in the OATT.
These losses shall be effective until modified by FERC, pursuant to
application by the Company or PJM under Section 205 of the Federal
Power Act or Southeastern Power Administration under Section 206 of the
Federal Power Act or otherwise.
Billing Month: The billing month for power sold under this schedule
shall end at 12:00 midnight on the last day of each calendar month.
Wholesale Power Rate Schedule VA-3-E
Availability: This rate schedule shall be available to public
bodies and cooperatives (any one of whom is hereinafter called the
Customer) in Virginia and North Carolina to whom power may be scheduled
pursuant to contracts between the Government, Virginia Electric and
Power Company (hereinafter called the Company), the Company's
Transmission Operator, currently PJM Interconnection LLC (hereinafter
called PJM), and the Customer. The Government is responsible for
providing the scheduling. The Customer is responsible for providing a
transmission arrangement. Nothing in this rate schedule shall preclude
modifications to the aforementioned contracts to allow an eligible
customer to elect service under another rate schedule.
Applicability: This rate schedule shall be applicable to the sale
at wholesale of power and accompanying energy generated at the John H.
Kerr and Philpott Projects (hereinafter called the Projects) and sold
under appropriate contracts between the Government and the Customer.
Character of Service: The electric capacity and energy supplied
hereunder will be delivered at the Projects.
Monthly Rate: The initial base monthly rate for capacity, energy,
and generation services provided under this rate schedule for the
period specified shall be:
Initial Base Capacity Charge: $5.71 per kilowatt of total contract
demand per month.
Initial Base Energy Charge: 21.83 mills per kilowatt-hour.
The rates are based on a repayment study that projects that the
Kerr-Philpott System will produce the following net revenue available
for repayment by fiscal year and cumulative net revenue available for
repayment by fiscal year:
------------------------------------------------------------------------
Estimated annual Cumulative net
net revenue revenue
Fiscal year available for available for
repayment repayment
------------------------------------------------------------------------
2025.............................. $360,000 $360,000
2026.............................. 630,000 990,000
2027.............................. 4,000,000 4,990,000
2028.............................. 4,310,000 9,300,000
2029.............................. 4,460,000 13,760,000
2030.............................. 3,970,000 17,730,000
2031.............................. 4,150,000 21,880,000
2032.............................. 4,280,000 26,160,000
2033.............................. 4,430,000 30,590,000
2034.............................. 4,610,000 35,200,000
------------------------------------------------------------------------
The rates include a true-up of the capacity and energy rates based
on the variance of the actual cumulative net revenue available for
repayment from the planned cumulative net revenue available for
repayment in the table above. For every $100,000 under-recovery of the
planned cumulative net revenue available for repayment, Southeastern
will increase the base capacity charge by $0.02 per kilowatt per month,
up to a maximum of $0.75 per kilowatt per month, and increase the base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt per hour, to be implemented April 1 of the next
fiscal year. For every $100,000 over-recovery of the planned cumulative
net revenue available for repayment, Southeastern will reduce the
current base capacity charge by $0.02 per kilowatt per month, up to a
maximum of $0.75 per kilowatt per month but not below the initial base
capacity charge set in the rate filing, and reduce the current base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt-hour but not below the initial base energy charge
set in the rate filing, to be implemented April 1 of the next fiscal
year. Southeastern will give written notice to the customers of the
amount of the true-up to the capacity and energy rates by February 1 of
the next fiscal year.
Additional rates for Transmission and Ancillary Services provided
under this rate schedule shall be the rates charged Southeastern Power
Administration by the Company or PJM. Future adjustments to these rates
will become effective upon acceptance for filing by the Federal Energy
Regulatory Commission (FERC) of the Company's rate.
Ancillary Services: 8.24 mills per kilowatt-hour of energy
estimated as of March 2025, is presented for illustrative purposes.
The initial charge for transmission and Ancillary Services will be
the Customer's ratable share of the charges for transmission,
distribution, and ancillary services paid by the Government. The
charges for
[[Page 44671]]
transmission and ancillary services are governed by and subject to
refund based upon the determination in proceedings before FERC
involving the Company's or PJM's Open Access Transmission Tariff
(OATT).
Proceedings before FERC involving the OATT or the Distribution
charge may result in the separation of charges currently included in
the transmission rate. In this event, the Government may charge the
Customer for any and all separate transmission, ancillary services, and
distribution charges paid by the Government in behalf of the Customer.
These charges could be recovered through a capacity charge or an energy
charge, as determined by the Government.
Tandem Transmission Charge: $3.33 per kilowatt of total contract
demand per month, as an estimated cost as of March 2025.
The tandem transmission charge will recover the cost of
transmitting power from a project to the border of another transmitting
system. This rate will be a formulary rate based on the cost to the
Government for transmission of power from the Philpott project to the
border of the Virginia Electric and Power Company System and the cost
to the Government for transmission of power from the John H. Kerr
Project to the border of the Duke Energy Progress System. These charges
could be recovered through a capacity charge or an energy charge, as
determined by the Government.
Transmission and Ancillary Services: The charges for transmission
and ancillary services shall be governed by and subject to refund based
upon the determination in the proceeding involving the Company's or
PJM's OATT.
Capacity Performance Non-Performance Charge: Requirements of the
PJM capacity performance market may lead to non-performance charges to
Southeastern. These non-performance charges, if incurred, will be
allocated to the capacity delivered in PJM (currently 120,100
kilowatts) in the month incurred.
Contract Demand: The contract demand is the amount of capacity in
kilowatts stated in the contract which the Government is obligated to
supply and the Customer is entitled to receive.
Energy to be Furnished by the Government: The Government will sell
to the Customer and the Customer will purchase from the Government
energy each billing month equivalent to a percentage specified by
contract of the energy made available to the Company (less applicable
losses). The Customer's contract demand and accompanying energy will be
allocated proportionately to its individual delivery points served from
the Company's system. The applicable energy loss factor for
transmission is specified in the OATT.
These losses shall be effective until modified by the Federal
Energy Regulatory Commission, pursuant to application by the Company or
PJM under Section 205 of the Federal Power Act or Southeastern Power
Administration under Section 206 of the Federal Power Act or otherwise.
Billing Month: The billing month for power sold under this schedule
shall end at 12:00 midnight on the last day of each calendar month.
Wholesale Power Rate Schedule VA-4-E
Availability: This rate schedule shall be available to public
bodies and cooperatives (any one of whom is hereinafter called the
Customer) in Virginia and North Carolina served through the
transmission facilities of Virginia Electric and Power Company
(hereinafter called the Company) and PJM Interconnection LLC
(hereinafter called PJM). The Customer has chosen to self-schedule and
does not receive Government power under an arrangement where the
Company schedules the power and provides a credit on the Customer's
bill for Government power. The Customer is responsible for providing a
scheduling arrangement with the Government and for providing a
transmission arrangement. Nothing in this rate schedule shall preclude
modifications to the aforementioned contracts to allow an eligible
customer to elect service under another rate schedule.
Applicability: This rate schedule shall be applicable to the sale
at wholesale of power and accompanying energy generated at the John H.
Kerr and Philpott Projects (hereinafter called the Projects) and sold
under appropriate contracts between the Government and the Customer.
Character of Service: The electric capacity and energy supplied
hereunder will be delivered at the Projects.
Monthly Rate: The initial base monthly rate for capacity, energy,
and generation services provided under this rate schedule for the
period specified shall be:
Initial Base Capacity Charge: $5.71 per kilowatt of total contract
demand per month.
Initial Base Energy Charge: 21.83 mills per kilowatt-hour.
The rates are based on a repayment study that projects that the
Kerr-Philpott System will produce the following net revenue available
for repayment by fiscal year and cumulative net revenue available for
repayment by fiscal year:
------------------------------------------------------------------------
Estimated annual Cumulative net
net revenue revenue
Fiscal year available for available for
repayment repayment
------------------------------------------------------------------------
2025.............................. $360,000 $360,000
2026.............................. 630,000 990,000
2027.............................. 4,000,000 4,990,000
2028.............................. 4,310,000 9,300,000
2029.............................. 4,460,000 13,760,000
2030.............................. 3,970,000 17,730,000
2031.............................. 4,150,000 21,880,000
2032.............................. 4,280,000 26,160,000
2033.............................. 4,430,000 30,590,000
2034.............................. 4,610,000 35,200,000
------------------------------------------------------------------------
The rates include a true-up of the capacity and energy rates based
on the variance of the actual cumulative net revenue available for
repayment from the planned cumulative net revenue available for
repayment in the table above. For every $100,000 under-recovery of the
planned cumulative net revenue available for repayment, Southeastern
will increase the base capacity charge by $0.02 per kilowatt per month,
up to a maximum of $0.75 per kilowatt per month, and increase the base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt per hour, to be implemented April 1 of the next
fiscal year. For every $100,000 over-recovery of the planned cumulative
net revenue available for repayment, Southeastern will reduce the
current base capacity charge by $0.02 per kilowatt per month, up to a
maximum of $0.75 per kilowatt per month but not below the initial base
capacity charge set in the rate filing, and reduce the current base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt-hour but not below the initial base energy charge
set in the rate filing, to be implemented April 1 of the next fiscal
year. Southeastern will give written notice to the customers of the
amount of the true-up to the capacity and energy rates by February 1 of
the next fiscal year.
Additional rates for transmission and ancillary services provided
under this rate schedule shall be the rates charged Southeastern Power
Administration by the Company or PJM. Future adjustments to these rates
will become effective upon acceptance for filing by the Federal Energy
Regulatory Commission (FERC) of the Company's rate.
Ancillary Services: 8.24 mills per kilowatt-hour of energy
estimated as of March 2025, is presented for illustrative purposes.
The initial charge for transmission and Ancillary Services will be
the Customer's ratable share of the charges
[[Page 44672]]
for transmission, distribution, and ancillary services paid by the
Government. The charges for transmission and ancillary services are
governed by and subject to refund based upon the determination in
proceedings before FERC involving the Company's or PJM's Open Access
Transmission Tariff (OATT).
Proceedings before FERC involving the OATT or the Distribution
charge may result in the separation of charges currently included in
the transmission rate. In this event, the Government may charge the
Customer for any and all separate transmission, ancillary services, and
distribution charges paid by the Government in behalf of the Customer.
These charges could be recovered through a capacity charge or an energy
charge, as determined by the Government.
Tandem Transmission Charge: $3.33 per kilowatt of total contract
demand per month, as an estimated cost as of March 2025.
The tandem transmission charge will recover the cost of
transmitting power from a project to the border of another transmitting
system. This rate will be a formulary rate based on the cost to the
Government for transmission of power from the Philpott project to the
border of the Virginia Electric and Power Company System and the cost
to the Government for transmission of power from the John H. Kerr
Project to the border of the Duke Energy Progress System. These charges
could be recovered through a capacity charge or an energy charge, as
determined by the Government.
Transmission and Ancillary Services: The charges for transmission
and ancillary services shall be governed by and subject to refund based
upon the determination in the proceeding involving the Company's or
PJM's OATT.
Capacity Performance Non-Performance Charge: Requirements of the
PJM capacity performance market may lead to non-performance charges to
Southeastern. These non-performance charges, if incurred, will be
allocated to the capacity delivered in PJM (currently 120,100
kilowatts) in the month incurred.
Contract Demand: The contract demand is the amount of capacity in
kilowatts stated in the contract which the Government is obligated to
supply and the Customer is entitled to receive.
Energy to be Furnished by the Government: The Government will sell
to the Customer and the Customer will purchase from the Government
energy each billing month equivalent to a percentage specified by
contract of the energy made available to the Company (less applicable
losses). The Customer's contract demand and accompanying energy will be
allocated proportionately to its individual delivery points served from
the Company's system. The applicable energy loss factor for
transmission is specified in the OATT.
These losses shall be effective until modified by FERC, pursuant to
application by the Company or PJM under Section 205 of the Federal
Power Act or Southeastern Power Administration under Section 206 of the
Federal Power Act or otherwise.
Billing Month: The billing month for power sold under this schedule
shall end at 12:00 midnight on the last day of each calendar month.
Wholesale Power Rate Schedule DEP-1-E
Availability: This rate schedule shall be available to public
bodies and cooperatives (any one of whom is hereinafter called the
Customer) in North Carolina and South Carolina to whom power may be
transmitted and scheduled pursuant to contracts between the Government
and Duke Energy Progress (formerly known as Carolina Power & Light
Company and hereinafter called the Company) and the Customer. This rate
schedule is applicable to customers receiving power from the Government
on an arrangement where the Company schedules the power and provides
the Customer a credit on their bill for Government power. Nothing in
this rate schedule shall preclude modifications to the aforementioned
contracts to allow an eligible customer to elect service under another
rate schedule.
Applicability: This rate schedule shall be applicable to the sale
at wholesale of power and accompanying energy generated at the John H.
Kerr and Philpott Projects and sold under appropriate contracts between
the Government and the Customer.
Character of Service: The electric capacity and energy supplied
hereunder will be delivered at the delivery points of the Customer on
the Company's transmission and distribution system.
Monthly Rate: The initial base monthly rate for capacity, energy,
and generation services provided under this rate schedule for the
period specified shall be:
Initial Base Capacity Charge: $5.71 per kilowatt of total contract
demand per month.
Initial Base Energy Charge: 21.83 mills per kilowatt-hour.
The rates are based on a repayment study that projects that the
Kerr-Philpott System will produce the following net revenue available
for repayment by fiscal year and cumulative net revenue available for
repayment by fiscal year:
------------------------------------------------------------------------
Estimated annual Cumulative net
net revenue revenue
Fiscal year available for available for
repayment repayment
------------------------------------------------------------------------
2025.............................. $360,000 $360,000
2026.............................. 630,000 990,000
2027.............................. 4,000,000 4,990,000
2028.............................. 4,310,000 9,300,000
2029.............................. 4,460,000 13,760,000
2030.............................. 3,970,000 17,730,000
2031.............................. 4,150,000 21,880,000
2032.............................. 4,280,000 26,160,000
2033.............................. 4,430,000 30,590,000
2034.............................. 4,610,000 35,200,000
------------------------------------------------------------------------
The rates include a true-up of the capacity and energy rates based
on the variance of the actual cumulative net revenue available for
repayment from the planned cumulative net revenue available for
repayment in the table above. For every $100,000 under-recovery of the
planned cumulative net revenue available for repayment, Southeastern
will increase the base capacity charge by $0.02 per kilowatt per month,
up to a maximum of $0.75 per kilowatt per month, and increase the base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt per hour, to be implemented April 1 of the next
fiscal year. For every $100,000 over-recovery of the planned cumulative
net revenue available for repayment, Southeastern will reduce the
current base capacity charge by $0.02 per kilowatt per month, up to a
maximum of $0.75 per kilowatt per month but not below the initial base
capacity charge set in the rate filing, and reduce the current base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt-hour but not below the initial base energy charge
set in the rate filing, to be implemented April 1 of the next fiscal
year. Southeastern will give written notice to the customers of the
amount of the true-up to the capacity and energy rates by February 1 of
the next fiscal year.
Additional rates for transmission and ancillary services provided
under this rate schedule shall be the rates charged Southeastern Power
Administration by the Company. Future adjustments to these rates will
become effective upon acceptance for filing by the Federal Energy
Regulatory Commission (FERC) of the Company's rate.
Transmission: $2.3955 per kilowatt of total contract demand per
month as of March 2025, is presented for illustrative purposes.
The initial transmission charge will be the Customer's ratable
share of the transmission and distribution charges
[[Page 44673]]
paid by the Government. The rate is subject to periodic adjustment and
will be computed in accordance with the terms of the Government-Company
contract.
Proceedings before FERC involving the Company's Open Access
Transmission Tariff (OATT) or the distribution charge may result in the
separation of charges currently included in the transmission rate. In
this event, the Government may charge the Customer for any and all
separate transmission and distribution charges paid by the Government
in behalf of the Customer. These charges could be recovered through a
capacity charge or an energy charge, as determined by the Government.
Tandem Transmission Charge: $3.33 per kilowatt of total contract
demand per month, as an estimated cost as of March 2025.
The tandem transmission charge will recover the cost of
transmitting power from a project to the border of another transmitting
system. This rate will be a formulary rate based on the cost to the
Government for transmission of power from the Philpott project to the
border of the Virginia Electric and Power Company System and the cost
to the Government for transmission of power from the John H. Kerr
Project to the border of the Duke Energy Progress System. These charges
could be recovered through a capacity charge or an energy charge, as
determined by the Government.
Transmission and Ancillary Services: The charges for transmission
and ancillary services shall be governed by and subject to refund based
upon the determination in the proceeding involving the Company's or
PJM's OATT.
Contract Demand: The contract demand is the amount of capacity in
kilowatts stated in the contract which the Government is obligated to
supply and the Customer is entitled to receive.
Energy to be Furnished by the Government: The Government will sell
to the Customer and the Customer will purchase from the Government
energy each billing month equivalent to a percentage specified by
contract of the energy made available to the Company (less applicable
losses). The Customer's contract demand and accompanying energy will be
allocated proportionately to its individual delivery points served from
the Company's system. The applicable energy loss factor for
transmission, in accordance with the Government-Company contract, is
six (6) per cent. This loss factor will be governed by the terms of the
Government-Company contract.
Billing Month: The billing month for power sold under this schedule
shall end at 12:00 midnight on the last day of each calendar month.
Wholesale Power Rate Schedule DEP-2-E
Availability: This rate schedule shall be available to public
bodies and cooperatives (any one of whom is hereinafter called the
Customer) in North Carolina and South Carolina to whom power may be
transmitted pursuant to contracts between the Government and Duke
Energy Progress (formerly known as Carolina Power & Light Company and
hereinafter called the Company) and the Customer. The Customer has
chosen to self-schedule and does not receive Government power under an
arrangement where the Company schedules the power and provides a credit
on the Customer's bill for Government power. The Customer is
responsible for providing a scheduling arrangement with the Government.
The Government is responsible for arranging transmission with the
Company. Nothing in this rate schedule shall preclude modifications to
the aforementioned contracts to allow an eligible customer to elect
service under another rate schedule.
Applicability: This rate schedule shall be applicable to the sale
at wholesale of power and accompanying energy generated at the John H.
Kerr and Philpott Projects and sold under appropriate contracts between
the Government and the Customer.
Character of Service: The electric capacity and energy supplied
hereunder will be delivered at the delivery points of the Customer on
the Company's transmission and distribution system.
Monthly Rate: The initial base monthly rate for capacity, energy,
and generation services provided under this rate schedule for the
period specified shall be:
Initial Base Capacity Charge: $5.71 per kilowatt of total contract
demand per month.
Initial Base Energy Charge: 21.83 mills per kilowatt-hour.
The rates are based on a repayment study that projects that the
Kerr-Philpott System will produce the following net revenue available
for repayment by fiscal year and cumulative net revenue available for
repayment by fiscal year:
------------------------------------------------------------------------
Estimated annual Cumulative net
net revenue revenue
Fiscal year available for available for
repayment repayment
------------------------------------------------------------------------
2025.............................. $360,000 $360,000
2026.............................. 630,000 990,000
2027.............................. 4,000,000 4,990,000
2028.............................. 4,310,000 9,300,000
2029.............................. 4,460,000 13,760,000
2030.............................. 3,970,000 17,730,000
2031.............................. 4,150,000 21,880,000
2032.............................. 4,280,000 26,160,000
2033.............................. 4,430,000 30,590,000
2034.............................. 4,610,000 35,200,000
------------------------------------------------------------------------
The rates include a true-up of the capacity and energy rates based
on the variance of the actual cumulative net revenue available for
repayment from the planned cumulative net revenue available for
repayment in the table above. For every $100,000 under-recovery of the
planned cumulative net revenue available for repayment, Southeastern
will increase the base capacity charge by $0.02 per kilowatt per month,
up to a maximum of $0.75 per kilowatt per month, and increase the base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt per hour, to be implemented April 1 of the next
fiscal year. For every $100,000 over-recovery of the planned cumulative
net revenue available for repayment, Southeastern will reduce the
current base capacity charge by $0.02 per kilowatt per month, up to a
maximum of $0.75 per kilowatt per month but not below the initial base
capacity charge set in the rate filing, and reduce the current base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt-hour but not below the initial base energy charge
set in the rate filing, to be implemented April 1 of the next fiscal
year. Southeastern will give written notice to the customers of the
amount of the true-up to the capacity and energy rates by February 1 of
the next fiscal year.
Additional rates for transmission and ancillary services provided
under this rate schedule shall be the rates charged Southeastern Power
Administration by the company. Future adjustments to these rates will
become effective upon acceptance for filing by the Federal Energy
Regulatory Commission (FERC) of the Company's rate.
Transmission: $2.3955 per kilowatt of total contract demand per
month as of March 2025, is presented for illustrative purposes.
The initial transmission charge will be the Customer's ratable
share of the transmission and distribution charges paid by the
Government. The rate is subject to periodic adjustment and will be
computed in accordance with the terms of the Government-Company
contract.
Proceedings before FERC involving the Company's Open Access
[[Page 44674]]
Transmission Tariff (OATT) or the distribution charge may result in the
separation of charges currently included in the transmission rate. In
this event, the Government may charge the Customer for any and all
separate transmission and distribution charges paid by the Government
in behalf of the Customer. These charges could be recovered through a
capacity charge or an energy charge, as determined by the Government.
Tandem Transmission Charge: $3.33 per kilowatt of total contract
demand per month, as an estimated cost as of March 2025.
The tandem transmission charge will recover the cost of
transmitting power from a project to the border of another transmitting
system. This rate will be a formulary rate based on the cost to the
Government for transmission of power from the Philpott project to the
border of the Virginia Electric and Power Company System and the cost
to the Government for transmission of power from the John H. Kerr
Project to the border of the Duke Energy Progress System. These charges
could be recovered through a capacity charge or an energy charge, as
determined by the Government.
Transmission and Ancillary Services: The charges for transmission
and ancillary services shall be governed by and subject to refund based
upon the determination in the proceeding involving the Company's or
PJM's OATT.
Contract Demand: The contract demand is the amount of capacity in
kilowatts stated in the contract which the Government is obligated to
supply and the Customer is entitled to receive.
Energy to be Furnished by the Government: The Government will sell
to the Customer and the Customer will purchase from the Government
energy each billing month equivalent to a percentage specified by
contract of the energy made available to the Company (less applicable
losses). The Customer's contract demand and accompanying energy will be
allocated proportionately to its individual delivery points served from
the Company's system. The applicable energy loss factor for
transmission, in accordance with the Government-Company contract, is
six (6) per cent. This loss factor will be governed by the terms of the
Government-Company contract.
Billing Month: The billing month for power sold under this schedule
shall end at 12:00 midnight on the last day of each calendar month.
Wholesale Power Rate Schedule DEP-3-E
Availability: This rate schedule shall be available to public
bodies and cooperatives (any one of whom is hereinafter called the
Customer) in North Carolina and South Carolina to whom power may be
scheduled pursuant to contracts between the Government and Duke Energy
Progress (formerly known as Carolina Power & Light Company and
hereinafter called the Company) and the Customer. The Government is
responsible for providing the scheduling. The Customer is responsible
for providing a transmission arrangement. Nothing in this rate schedule
shall preclude modifications to the aforementioned contracts to allow
an eligible customer to elect service under another rate schedule.
Applicability: This rate schedule shall be applicable to the sale
at wholesale of power and accompanying energy generated at the John H.
Kerr and Philpott Projects (hereinafter called the Projects) and sold
under appropriate contracts between the Government and the Customer.
Character of Service: The electric capacity and energy supplied
hereunder will be delivered at the Projects.
Monthly Rate: The initial base monthly rate for capacity, energy,
and generation services provided under this rate schedule for the
period specified shall be:
Initial Base Capacity Charge: $5.71 per kilowatt of total contract
demand per month.
Initial Base Energy Charge: 21.83 mills per kilowatt-hour.
The rates are based on a repayment study that projects that the
Kerr-Philpott System will produce the following net revenue available
for repayment by fiscal year and cumulative net revenue available for
repayment by fiscal year:
------------------------------------------------------------------------
Estimated annual Cumulative net
net revenue revenue
Fiscal year available for available for
repayment repayment
------------------------------------------------------------------------
2025.............................. $360,000 $360,000
2026.............................. 630,000 990,000
2027.............................. 4,000,000 4,990,000
2028.............................. 4,310,000 9,300,000
2029.............................. 4,460,000 13,760,000
2030.............................. 3,970,000 17,730,000
2031.............................. 4,150,000 21,880,000
2032.............................. 4,280,000 26,160,000
2033.............................. 4,430,000 30,590,000
2034.............................. 4,610,000 35,200,000
------------------------------------------------------------------------
The rates include a true-up of the capacity and energy rates based
on the variance of the actual cumulative net revenue available for
repayment from the planned cumulative net revenue available for
repayment in the table above. For every $100,000 under-recovery of the
planned cumulative net revenue available for repayment, Southeastern
will increase the base capacity charge by $0.02 per kilowatt per month,
up to a maximum of $0.75 per kilowatt per month, and increase the base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt per hour, to be implemented April 1 of the next
fiscal year. For every $100,000 over-recovery of the planned cumulative
net revenue available for repayment, Southeastern will reduce the
current base capacity charge by $0.02 per kilowatt per month, up to a
maximum of $0.75 per kilowatt per month but not below the initial base
capacity charge set in the rate filing, and reduce the current base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt-hour but not below the initial base energy charge
set in the rate filing, to be implemented April 1 of the next fiscal
year. Southeastern will give written notice to the customers of the
amount of the true-up to the capacity and energy rates by February 1 of
the next fiscal year.
Additional rates for transmission and ancillary services provided
under this rate schedule shall be the rates charged Southeastern Power
Administration by the Company. Future adjustments to these rates will
become effective upon acceptance for filing by the Federal Energy
Regulatory Commission (FERC) of the Company's rate.
Proceedings before FERC involving the Company's Open Access
Transmission Tariff (OATT) or the distribution charge may result in the
separation of charges currently included in the transmission rate. In
this event, the Government may charge the Customer for any and all
separate transmission and distribution charges paid by the Government
on behalf of the Customer.
Tandem Transmission Charge: $3.33 per kilowatt of total contract
demand per month, as an estimated cost as of March 2025.
The tandem transmission charge will recover the cost of
transmitting power from a project to the border of another transmitting
system. This rate will be a formulary rate based on the cost to the
Government for transmission of power from the Philpott project to the
border of the Virginia Electric and Power Company System and the cost
to the Government for transmission of power from the John H. Kerr
Project to the border of the Duke Energy Progress System. These charges
could be recovered through a capacity charge or an energy charge, as
determined by the Government.
[[Page 44675]]
Transmission and Ancillary Services: The charges for transmission
and ancillary services shall be governed by and subject to refund based
upon the determination in the proceeding involving the Company's or
PJM's OATT.
Contract Demand: The contract demand is the amount of capacity in
kilowatts stated in the contract which the Government is obligated to
supply and the Customer is entitled to receive.
Energy to be Furnished by the Government: The Government will sell
to the Customer and the Customer will purchase from the Government
energy each billing month equivalent to a percentage specified by
contract of the energy made available to the Company (less applicable
losses). The Customer's contract demand and accompanying energy will be
allocated proportionately to its individual delivery points served from
the Company's system. The applicable energy loss factor for
transmission, in accordance with the Government-Company contract, is
six (6) per cent. This loss factor will be governed by the terms of the
Government-Company contract.
Billing Month: The billing month for power sold under this schedule
shall end at 12:00 midnight on the last day of each calendar month.
Wholesale Power Rate Schedule DEP-4-E
Availability: This rate schedule shall be available to public
bodies and cooperatives (any one of whom is hereinafter called the
Customer) in North Carolina and South Carolina served through the
transmission facilities of Duke Energy Progress (formerly known as
Carolina Power & Light Company and hereinafter called the Company). The
Customer has chosen to self-schedule and does not receive Government
power under an arrangement where the Company schedules the power and
provides a credit on the Customer's bill for Government power. The
Customer is responsible for providing a scheduling arrangement with the
Government and for providing a transmission arrangement. Nothing in
this rate schedule shall preclude modifications to the aforementioned
contracts to allow an eligible customer to elect service under another
rate schedule.
Applicability: This rate schedule shall be applicable to the sale
at wholesale of power and accompanying energy generated at the John H.
Kerr and Philpott Projects (hereinafter called the Projects) and sold
under appropriate contracts between the Government and the Customer.
Character of Service: The electric capacity and energy supplied
hereunder will be delivered at the Projects.
Monthly Rate: The initial base monthly rate for capacity, energy,
and generation services provided under this rate schedule for the
period specified shall be:
Initial Base Capacity Charge: $5.71 per kilowatt of total contract
demand per month.
Initial Base Energy Charge: 21.83 mills per kilowatt-hour.
The rates are based on a repayment study that projects that the
Kerr-Philpott System will produce the following net revenue available
for repayment by fiscal year and cumulative net revenue available for
repayment by fiscal year:
------------------------------------------------------------------------
Estimated annual Cumulative net
net revenue revenue
Fiscal year available for available for
repayment repayment
------------------------------------------------------------------------
2025.............................. $360,000 $360,000
2026.............................. 630,000 990,000
2027.............................. 4,000,000 4,990,000
2028.............................. 4,310,000 9,300,000
2029.............................. 4,460,000 13,760,000
2030.............................. 3,970,000 17,730,000
2031.............................. 4,150,000 21,880,000
2032.............................. 4,280,000 26,160,000
2033.............................. 4,430,000 30,590,000
2034.............................. 4,610,000 35,200,000
------------------------------------------------------------------------
The rates include a true-up of the capacity and energy rates based
on the variance of the actual cumulative net revenue available for
repayment from the planned cumulative net revenue available for
repayment in the table above. For every $100,000 under-recovery of the
planned cumulative net revenue available for repayment, Southeastern
will increase the base capacity charge by $0.02 per kilowatt per month,
up to a maximum of $0.75 per kilowatt per month, and increase the base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt per hour, to be implemented April 1 of the next
fiscal year. For every $100,000 over-recovery of the planned cumulative
net revenue available for repayment, Southeastern will reduce the
current base capacity charge by $0.02 per kilowatt per month, up to a
maximum of $0.75 per kilowatt per month but not below the initial base
capacity charge set in the rate filing, and reduce the current base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt-hour but not below the initial base energy charge
set in the rate filing, to be implemented April 1 of the next fiscal
year. Southeastern will give written notice to the customers of the
amount of the true-up to the capacity and energy rates by February 1 of
the next fiscal year.
Additional rates for transmission and ancillary services provided
under this rate schedule shall be the rates charged Southeastern Power
Administration by the Company. Future adjustments to these rates will
become effective upon acceptance for filing by the Federal Energy
Regulatory Commission (FERC) of the Company's rate.
$3.33 per kilowatt of total contract demand per month, as an
estimated cost as of March 2025.
The tandem transmission charge will recover the cost of
transmitting power from a project to the border of another transmitting
system. This rate will be a formulary rate based on the cost to the
Government for transmission of power from the Philpott project to the
border of the Virginia Electric and Power Company System and the cost
to the Government for transmission of power from the John H. Kerr
Project to the border of the Duke Energy Progress System. These charges
could be recovered through a capacity charge or an energy charge, as
determined by the Government.
Transmission and Ancillary Services: The charges for transmission
and ancillary services shall be governed by and subject to refund based
upon the determination in the proceeding involving the Company's or
PJM's OATT.
Contract Demand: The contract demand is the amount of capacity in
kilowatts stated in the contract which the Government is obligated to
supply and the Customer is entitled to receive.
Energy to be Furnished by the Government: The Government will sell
to the Customer and the Customer will purchase from the Government
energy each billing month equivalent to a percentage specified by
contract of the energy made available to the Company (less applicable
losses). The Customer's contract demand and accompanying energy will be
allocated proportionately to its individual delivery points served from
the Company's system. The applicable energy loss factor for
transmission, in accordance with the Government-Company contract, is
six (6) per cent. This loss factor will be governed by the terms of the
Government-Company contract.
Billing Month: The billing month for power sold under this schedule
shall end at 12:00 midnight on the last day of each calendar month.
Wholesale Power Rate Schedule AP-1-E
Availability: This rate schedule shall be available to public
bodies and cooperatives (any one of whom is hereinafter called the
Customer) in
[[Page 44676]]
Virginia to whom power may be transmitted and scheduled pursuant to
contracts between the Government, American Electric Power Service
Corporation (hereinafter called the Company), the Company's
Transmission Operator, currently PJM Interconnection LLC (hereinafter
called PJM), and the Customer. This rate schedule is applicable to
customers receiving power from the Government on an arrangement where
the Company schedules the power and provides the Customer a credit on
their bill for Government power. Nothing in this rate schedule shall
preclude modifications to the aforementioned contracts to allow an
eligible customer to elect service under another rate schedule.
Applicability: This rate schedule shall be applicable to the sale
at wholesale of power and accompanying energy generated at the John H.
Kerr and Philpott Projects and sold under appropriate contracts between
the Government and the Customer.
Character of Service: The electric capacity and energy supplied
hereunder will be delivered at the delivery points of the Customer on
the Company's transmission and distribution system.
Monthly Rate: The initial base monthly rate for capacity, energy,
and generation services provided under this rate schedule for the
period specified shall be:
Initial Base Capacity Charge: $5.71 per kilowatt of total contract
demand per month.
Initial Base Energy Charge: 21.83 mills per kilowatt-hour.
The rates are based on a repayment study that projects that the
Kerr-Philpott System will produce the following net revenue available
for repayment by fiscal year and cumulative net revenue available for
repayment by fiscal year:
------------------------------------------------------------------------
Estimated annual Cumulative net
net revenue revenue
Fiscal year available for available for
repayment repayment
------------------------------------------------------------------------
2025.............................. $360,000 $360,000
2026.............................. 630,000 990,000
2027.............................. 4,000,000 4,990,000
2028.............................. 4,310,000 9,300,000
2029.............................. 4,460,000 13,760,000
2030.............................. 3,970,000 17,730,000
2031.............................. 4,150,000 21,880,000
2032.............................. 4,280,000 26,160,000
2033.............................. 4,430,000 30,590,000
2034.............................. 4,610,000 35,200,000
------------------------------------------------------------------------
The rates include a true-up of the capacity and energy rates based
on the variance of the actual cumulative net revenue available for
repayment from the planned cumulative net revenue available for
repayment in the table above. For every $100,000 under-recovery of the
planned cumulative net revenue available for repayment, Southeastern
will increase the base capacity charge by $0.02 per kilowatt per month,
up to a maximum of $0.75 per kilowatt per month, and increase the base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt per hour, to be implemented April 1 of the next
fiscal year. For every $100,000 over-recovery of the planned cumulative
net revenue available for repayment, Southeastern will reduce the
current base capacity charge by $0.02 per kilowatt per month, up to a
maximum of $0.75 per kilowatt per month but not below the initial base
capacity charge set in the rate filing, and reduce the current base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt-hour but not below the initial base energy charge
set in the rate filing, to be implemented April 1 of the next fiscal
year. Southeastern will give written notice to the customers of the
amount of the true-up to the capacity and energy rates by February 1 of
the next fiscal year.
Additional rates for transmission and ancillary services provided
under this rate schedule shall be the rates charged Southeastern Power
Administration by the Company. Future adjustments to these rates will
become effective upon acceptance for filing by the Federal Energy
Regulatory Commission (FERC) of the Company's rate.
Transmission: $7.53 per kilowatt of total contract demand per month
estimated as of March 2025, is presented for illustrative purposes.
Ancillary Services: 8.24 mills per kilowatt-hour of energy
estimated as of March 2025, is presented for illustrative purposes.
The initial charge for transmission and Ancillary Services will be
the Customer's ratable share of the charges for transmission,
distribution, and ancillary services paid by the Government. The
charges for transmission and ancillary services are governed by and
subject to refund based upon the determination in proceedings before
FERC involving the Company's or PJM's Open Access Transmission Tariff
(OATT).
Proceedings before FERC involving the OATT or the Distribution
charge may result in the separation of charges currently included in
the transmission rate. In this event, the Government may charge the
Customer for any and all separate transmission, ancillary services, and
distribution charges paid by the Government in behalf of the Customer.
These charges could be recovered through a capacity charge or an energy
charge, as determined by the Government.
Tandem Transmission Charge: $3.33 per kilowatt of total contract
demand per month, as an estimated cost as of March 2025.
The tandem transmission charge will recover the cost of
transmitting power from a project to the border of another transmitting
system. This rate will be a formulary rate based on the cost to the
Government for transmission of power from the Philpott project to the
border of the Virginia Electric and Power Company System and the cost
to the Government for transmission of power from the John H. Kerr
Project to the border of the Duke Energy Progress System. These charges
could be recovered through a capacity charge or an energy charge, as
determined by the Government.
Transmission and Ancillary Services: The charges for transmission
and ancillary services shall be governed by and subject to refund based
upon the determination in the proceeding involving the Company's or
PJM's OATT.
Capacity Performance Non-Performance Charge: Requirements of the
PJM capacity performance market may lead to non-performance charges to
Southeastern. These non-performance charges, if incurred, will be
allocated to the capacity delivered in PJM (currently 120,100
kilowatts) in the month incurred.
Contract Demand: The contract demand is the amount of capacity in
kilowatts stated in the contract which the Government is obligated to
supply and the Customer is entitled to receive.
Energy to be Furnished by the Government: The Government will sell
to the Customer and the Customer will purchase from the Government
energy each billing month equivalent to a percentage specified by
contract of the energy made available to the Company (less applicable
losses). The Customer's contract demand and accompanying energy will be
allocated proportionately to its individual delivery points served from
the Company's system. The applicable energy loss factor for
transmission is specified in the OATT.
These losses shall be effective until modified by the Federal
Energy Regulatory Commission, pursuant to application by the Company or
PJM under Section 205 of the Federal Power Act or Southeastern Power
Administration under Section 206 of the Federal Power Act or otherwise.
Billing Month: The billing month for power sold under this schedule
shall end at 12:00 midnight on the last day of each calendar month.
[[Page 44677]]
Wholesale Power Rate Schedule AP-2-E
Availability: This rate schedule shall be available to public
bodies and cooperatives (any one of whom is hereinafter called the
Customer) in Virginia to whom power may be transmitted pursuant to
contracts between the Government, American Electric Power Service
Corporation (hereinafter called the Company), the Company's
Transmission Operator, currently PJM Interconnection LLC (hereinafter
called PJM), and the Customer. The Customer has chosen to self-schedule
and does not receive Government power under an arrangement where the
Company schedules the power and provides a credit on the Customer's
bill for Government power. The Customer is responsible for providing a
scheduling arrangement with the Government. The Government is
responsible for arranging transmission with the Company. Nothing in
this rate schedule shall preclude modifications to the aforementioned
contracts to allow an eligible customer to elect service under another
rate schedule.
Applicability: This rate schedule shall be applicable to the sale
at wholesale of power and accompanying energy generated at the John H.
Kerr and Philpott Projects and sold under appropriate contracts between
the Government and the Customer.
Character of Service: The electric capacity and energy supplied
hereunder will be delivered at the delivery points of the Customer on
the Company's transmission and distribution system.
Monthly Rate: The initial base monthly rate for capacity, energy,
and generation services provided under this rate schedule for the
period specified shall be:
Initial Base Capacity Charge: $5.71 per kilowatt of total contract
demand per month.
Initial Base Energy Charge: 21.83 mills per kilowatt-hour.
The rates are based on a repayment study that projects that the
Kerr-Philpott System will produce the following net revenue available
for repayment by fiscal year and cumulative net revenue available for
repayment by fiscal year:
------------------------------------------------------------------------
Estimated annual Cumulative net
net revenue revenue
Fiscal year available for available for
repayment repayment
------------------------------------------------------------------------
2025.............................. $360,000 $360,000
2026.............................. 630,000 990,000
2027.............................. 4,000,000 4,990,000
2028.............................. 4,310,000 9,300,000
2029.............................. 4,460,000 13,760,000
2030.............................. 3,970,000 17,730,000
2031.............................. 4,150,000 21,880,000
2032.............................. 4,280,000 26,160,000
2033.............................. 4,430,000 30,590,000
2034.............................. 4,610,000 35,200,000
------------------------------------------------------------------------
The rates include a true-up of the capacity and energy rates based
on the variance of the actual cumulative net revenue available for
repayment from the planned cumulative net revenue available for
repayment in the table above. For every $100,000 under-recovery of the
planned cumulative net revenue available for repayment, Southeastern
will increase the base capacity charge by $0.02 per kilowatt per month,
up to a maximum of $0.75 per kilowatt per month, and increase the base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt per hour, to be implemented April 1 of the next
fiscal year. For every $100,000 over-recovery of the planned cumulative
net revenue available for repayment, Southeastern will reduce the
current base capacity charge by $0.02 per kilowatt per month, up to a
maximum of $0.75 per kilowatt per month but not below the initial base
capacity charge set in the rate filing, and reduce the current base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt-hour but not below the initial base energy charge
set in the rate filing, to be implemented April 1 of the next fiscal
year. Southeastern will give written notice to the customers of the
amount of the true-up to the capacity and energy rates by February 1 of
the next fiscal year.
Additional rates for transmission and ancillary services provided
under this rate schedule shall be the rates charged Southeastern Power
Administration by the Company. Future adjustments to these rates will
become effective upon acceptance for filing by the Federal Energy
Regulatory Commission (FERC) of the Company's rate.
Transmission: $7.53 per kilowatt of total contract demand per month
estimated as of March 2025, is presented for illustrative purposes.
Ancillary Services: 8.24 mills per kilowatt-hour of energy
estimated as of March 2025, is presented for illustrative purposes.
The initial charge for transmission and Ancillary Services will be
the Customer's ratable share of the charges for transmission,
distribution, and ancillary services paid by the Government. The
charges for transmission and ancillary services are governed by and
subject to refund based upon the determination in proceedings before
FERC involving the Company's or PJM's Open Access Transmission Tariff
(OATT).
Proceedings before FERC involving the OATT or the Distribution
charge may result in the separation of charges currently included in
the transmission rate. In this event, the Government may charge the
Customer for any and all separate transmission, ancillary services, and
distribution charges paid by the Government in behalf of the Customer.
These charges could be recovered through a capacity charge or an energy
charge, as determined by the Government.
Tandem Transmission Charge: $3.33 per kilowatt of total contract
demand per month, as an estimated cost as of March 2025.
The tandem transmission charge will recover the cost of
transmitting power from a project to the border of another transmitting
system. This rate will be a formulary rate based on the cost to the
Government for transmission of power from the Philpott project to the
border of the Virginia Electric and Power Company System and the cost
to the Government for transmission of power from the John H. Kerr
Project to the border of the Duke Energy Progress System. These charges
could be recovered through a capacity charge or an energy charge, as
determined by the Government.
Transmission and Ancillary Services: The charges for transmission
and ancillary services shall be governed by and subject to refund based
upon the determination in the proceeding involving the Company's or
PJM's OATT.
Capacity Performance Non-Performance Charge: Requirements of the
PJM capacity performance market may lead to non-performance charges to
Southeastern. These non-performance charges, if incurred, will be
allocated to the capacity delivered in PJM (currently 120,100
kilowatts) in the month incurred.
Contract Demand: The contract demand is the amount of capacity in
kilowatts stated in the contract which the Government is obligated to
supply and the Customer is entitled to receive.
Energy to be Furnished by the Government: The Government will sell
to the Customer and the Customer will purchase from the Government
energy each billing month equivalent to a percentage specified by
contract of the energy made available to the Company (less applicable
losses). The Customer's contract demand and accompanying energy will be
allocated proportionately to its individual delivery points served
[[Page 44678]]
from the Company's system. The applicable energy loss factor for
transmission is specified in the OATT.
These losses shall be effective until modified by the Federal
Energy Regulatory Commission, pursuant to application by American
Electric Power Service Corporation under Section 205 of the Federal
Power Act or Southeastern Power Administration under Section 206 of the
Federal Power Act or otherwise.
Billing Month: The billing month for power sold under this schedule
shall end at 12:00 midnight on the last day of each calendar month.
Wholesale Power Rate Schedule AP-3-E
Availability: This rate schedule shall be available to public
bodies and cooperatives (any one of whom is hereinafter called the
Customer) in Virginia to whom power may be scheduled pursuant to
contracts between the Government, American Electric Power Service
Corporation (hereinafter called the Company), PJM Interconnection LLC
(hereinafter called PJM), and the Customer. The Government is
responsible for providing the scheduling. The Customer is responsible
for providing a transmission arrangement. Nothing in this rate schedule
shall preclude modifications to the aforementioned contracts to allow
an eligible customer to elect service under another rate schedule.
Applicability: This rate schedule shall be applicable to the sale
at wholesale of power and accompanying energy generated at the John H.
Kerr and Philpott Projects (hereinafter called the Projects) and sold
under appropriate contracts between the Government and the Customer.
Character of Service: The electric capacity and energy supplied
hereunder will be delivered at the Projects.
Monthly Rate: The initial base monthly rate for capacity, energy,
and generation services provided under this rate schedule for the
period specified shall be:
Initial Base Capacity Charge: $5.71 per kilowatt of total contract
demand per month.
Initial Base Energy Charge: 21.83 mills per kilowatt-hour.
The rates are based on a repayment study that projects that the
Kerr-Philpott System will produce the following net revenue available
for repayment by fiscal year and cumulative net revenue available for
repayment by fiscal year:
------------------------------------------------------------------------
Estimated annual Cumulative net
net revenue revenue
Fiscal year available for available for
repayment repayment
------------------------------------------------------------------------
2025.............................. $360,000 $360,000
2026.............................. 630,000 990,000
2027.............................. 4,000,000 4,990,000
2028.............................. 4,310,000 9,300,000
2029.............................. 4,460,000 13,760,000
2030.............................. 3,970,000 17,730,000
2031.............................. 4,150,000 21,880,000
2032.............................. 4,280,000 26,160,000
2033.............................. 4,430,000 30,590,000
2034.............................. 4,610,000 35,200,000
------------------------------------------------------------------------
The rates include a true-up of the capacity and energy rates based
on the variance of the actual cumulative net revenue available for
repayment from the planned cumulative net revenue available for
repayment in the table above. For every $100,000 under-recovery of the
planned cumulative net revenue available for repayment, Southeastern
will increase the base capacity charge by $0.02 per kilowatt per month,
up to a maximum of $0.75 per kilowatt per month, and increase the base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt per hour, to be implemented April 1 of the next
fiscal year. For every $100,000 over-recovery of the planned cumulative
net revenue available for repayment, Southeastern will reduce the
current base capacity charge by $0.02 per kilowatt per month, up to a
maximum of $0.75 per kilowatt per month but not below the initial base
capacity charge set in the rate filing, and reduce the current base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt-hour but not below the initial base energy charge
set in the rate filing, to be implemented April 1 of the next fiscal
year. Southeastern will give written notice to the customers of the
amount of the true-up to the capacity and energy rates by February 1 of
the next fiscal year.
Additional rates for transmission and ancillary services provided
under this rate schedule shall be the rates charged Southeastern Power
Administration by the Company. Future adjustments to these rates will
become effective upon acceptance for filing by the Federal Energy
Regulatory Commission (FERC) of the Company's rate.
Ancillary Services: 8.24 mills per kilowatt-hour of energy
estimated as of March 2025, is presented for illustrative purposes.
The initial charge for transmission and Ancillary Services will be
the Customer's ratable share of the charges for transmission,
distribution, and ancillary services paid by the Government. The
charges for transmission and ancillary services are governed by and
subject to refund based upon the determination in proceedings before
FERC involving the Company's or PJM's Open Access Transmission Tariff
(OATT).
Proceedings before FERC involving the OATT or the Distribution
charge may result in the separation of charges currently included in
the transmission rate. In this event, the Government may charge the
Customer for any and all separate transmission, ancillary services, and
distribution charges paid by the Government in behalf of the Customer.
These charges could be recovered through a capacity charge or an energy
charge, as determined by the Government.
Tandem Transmission Charge: $3.33 per kilowatt of total contract
demand per month, as an estimated cost as of March 2025.
The tandem transmission charge will recover the cost of
transmitting power from a project to the border of another transmitting
system. This rate will be a formulary rate based on the cost to the
Government for transmission of power from the Philpott project to the
border of the Virginia Electric and Power Company System and the cost
to the Government for transmission of power from the John H. Kerr
Project to the border of the Duke Energy Progress System. These charges
could be recovered through a capacity charge or an energy charge, as
determined by the Government.
Transmission and Ancillary Services: The charges for transmission
and ancillary services shall be governed by and subject to refund based
upon the determination in the proceeding involving the Company's or
PJM's OATT.
Capacity Performance Non-Performance Charge: Requirements of the
PJM capacity performance market may lead to non-performance charges to
Southeastern. These non-performance charges, if incurred, will be
allocated to the capacity delivered in PJM (currently 120,100
kilowatts) in the month incurred.
Contract Demand: The contract demand is the amount of capacity in
kilowatts stated in the contract which the Government is obligated to
supply and the Customer is entitled to receive.
Energy to be Furnished by the Government: The Government will sell
to the Customer and the Customer will purchase from the Government
energy each billing month equivalent to a percentage specified by
contract of the energy made available to the Company (less applicable
losses). The Customer's contract demand and accompanying energy will be
allocated proportionately
[[Page 44679]]
to its individual delivery points served from the Company's system. The
applicable energy loss factor for transmission is specified in the
OATT.
These losses shall be effective until modified by FERC, pursuant to
application by the Company or PJM under Section 205 of the Federal
Power Act or Southeastern Power Administration under Section 206 of the
Federal Power Act or otherwise.
Billing Month: The billing month for power sold under this schedule
shall end at 12:00 midnight on the last day of each calendar month.
Wholesale Power Rate Schedule AP-4-E
Availability: This rate schedule shall be available to public
bodies and cooperatives (any one of whom is hereinafter called the
Customer) in Virginia served through the facilities of American
Electric Power Service Corporation (hereinafter called the Company) and
PJM Interconnection LLC (hereinafter called PJM). The Customer has
chosen to self-schedule and does not receive Government power under an
arrangement where the Company schedules the power and provides a credit
on the Customer's bill for Government power. The Customer is
responsible for providing a scheduling arrangement with the Government
and for providing a transmission arrangement. Nothing in this rate
schedule shall preclude modifications to the aforementioned contracts
to allow an eligible customer to elect service under another rate
schedule.
Applicability: This rate schedule shall be applicable to the sale
at wholesale of power and accompanying energy generated at the John H.
Kerr and Philpott Projects (hereinafter called the Projects) and sold
under appropriate contracts between the Government and the Customer.
Character of Service: The electric capacity and energy supplied
hereunder will be delivered at the Projects.
Monthly Rate: The initial base monthly rate for capacity, energy,
and generation services provided under this rate schedule for the
period specified shall be:
Initial Base Capacity Charge: $5.71 per kilowatt of total contract
demand per month.
Initial Base Energy Charge: 21.83 mills per kilowatt-hour.
The rates are based on a repayment study that projects that the
Kerr-Philpott System will produce the following net revenue available
for repayment by fiscal year and cumulative net revenue available for
repayment by fiscal year:
------------------------------------------------------------------------
Estimated annual Cumulative net
net revenue revenue
Fiscal year available for available for
repayment repayment
------------------------------------------------------------------------
2025.............................. $360,000 $360,000
2026.............................. 630,000 990,000
2027.............................. 4,000,000 4,990,000
2028.............................. 4,310,000 9,300,000
2029.............................. 4,460,000 13,760,000
2030.............................. 3,970,000 17,730,000
2031.............................. 4,150,000 21,880,000
2032.............................. 4,280,000 26,160,000
2033.............................. 4,430,000 30,590,000
2034.............................. 4,610,000 35,200,000
------------------------------------------------------------------------
The rates include a true-up of the capacity and energy rates based
on the variance of the actual cumulative net revenue available for
repayment from the planned cumulative net revenue available for
repayment in the table above. For every $100,000 under-recovery of the
planned cumulative net revenue available for repayment, Southeastern
will increase the base capacity charge by $0.02 per kilowatt per month,
up to a maximum of $0.75 per kilowatt per month, and increase the base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt per hour, to be implemented April 1 of the next
fiscal year. For every $100,000 over-recovery of the planned cumulative
net revenue available for repayment, Southeastern will reduce the
current base capacity charge by $0.02 per kilowatt per month, up to a
maximum of $0.75 per kilowatt per month but not below the initial base
capacity charge set in the rate filing, and reduce the current base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt-hour but not below the initial base energy charge
set in the rate filing, to be implemented April 1 of the next fiscal
year. Southeastern will give written notice to the customers of the
amount of the true-up to the capacity and energy rates by February 1 of
the next fiscal year.
Additional rates for Transmission and Ancillary Services provided
under this rate schedule shall be the rates charged Southeastern Power
Administration by the Company. Future adjustments to these rates will
become effective upon acceptance for filing by the Federal Energy
Regulatory Commission (FERC) of the Company's rate.
Ancillary Services: 8.24 mills per kilowatt-hour of energy
estimated as of March 2025, is presented for illustrative purposes.
The initial charge for transmission and Ancillary Services will be
the Customer's ratable share of the charges for transmission,
distribution, and ancillary services paid by the Government. The
charges for transmission and ancillary services are governed by and
subject to refund based upon the determination in proceedings before
FERC involving the Company's or PJM's Open Access Transmission Tariff
(OATT).
Proceedings before FERC involving the OATT or the Distribution
charge may result in the separation of charges currently included in
the transmission rate. In this event, the Government may charge the
Customer for any and all separate transmission, ancillary services, and
distribution charges paid by the Government in behalf of the Customer.
These charges could be recovered through a capacity charge or an energy
charge, as determined by the Government.
Tandem Transmission Charge: $3.33 per kilowatt of total contract
demand per month, as an estimated cost as of March 2025.
The tandem transmission charge will recover the cost of
transmitting power from a project to the border of another transmitting
system. This rate will be a formulary rate based on the cost to the
Government for transmission of power from the Philpott project to the
border of the Virginia Electric and Power Company System and the cost
to the Government for transmission of power from the John H. Kerr
Project to the border of the Duke Energy Progress System. These charges
could be recovered through a capacity charge or an energy charge, as
determined by the Government.
Transmission and Ancillary Services: The charges for transmission
and ancillary services shall be governed by and subject to refund based
upon the determination in the proceeding involving the Company's or
PJM's OATT.
Capacity Performance Non-Performance Charge: Requirements of the
PJM capacity performance market may lead to non-performance charges to
Southeastern. These non-performance charges, if incurred, will be
allocated to the capacity delivered in PJM (currently 120,100
kilowatts) in the month incurred.
Contract Demand: The contract demand is the amount of capacity in
kilowatts stated in the contract which the Government is obligated to
supply and the Customer is entitled to receive.
Energy to be Furnished by the Government: The Government will sell
to the Customer and the Customer will purchase from the Government
energy each billing month equivalent to a percentage specified by
contract of the energy made available to the Company (less applicable
losses). The Customer's contract demand and accompanying energy will be
allocated proportionately
[[Page 44680]]
to its individual delivery points served from the Company's system. The
applicable energy loss factor for transmission is specified in the
OATT.
These losses shall be effective until modified by the Federal
Energy Regulatory Commission, pursuant to application by the Company or
PJM under Section 205 of the Federal Power Act or Southeastern Power
Administration under Section 206 of the Federal Power Act or otherwise.
Billing Month: The billing month for power sold under this schedule
shall end at 12:00 midnight on the last day of each calendar month.
Wholesale Power Rate Schedule NC-1-E
Availability: This rate schedule shall be available to public
bodies and cooperatives (any one of whom is hereinafter called the
Customer) in Virginia and North Carolina to whom power may be
transmitted pursuant to a contract between the Government and Virginia
Electric and Power Company (hereinafter called the Virginia Power) and
PJM Interconnection LLC (hereinafter called PJM), scheduled pursuant to
a contract between the Government and Duke Energy Progress (formerly
known as Carolina Power & Light and hereinafter called DEP), and billed
pursuant to contracts between the Government and the Customer. Nothing
in this rate schedule shall preclude modifications to the
aforementioned contracts to allow an eligible customer to elect service
under another rate schedule.
Applicability: This rate schedule shall be applicable to the sale
at wholesale of power and accompanying energy generated at the John H.
Kerr and Philpott Projects and sold under appropriate contracts between
the Government and the Customer.
Character of Service: The electric capacity and energy supplied
hereunder will be delivered at the delivery points of the Customer on
the Virginia Power's transmission and distribution system.
Monthly Rate: The initial base monthly rate for capacity, energy,
and generation services provided under this rate schedule for the
period specified shall be:
Initial Base Capacity Charge: $5.71 per kilowatt of total contract
demand per month.
Initial Base Energy Charge: 21.83 mills per kilowatt-hour.
The rates are based on a repayment study that projects that the
Kerr-Philpott System will produce the following net revenue available
for repayment by fiscal year and cumulative net revenue available for
repayment by fiscal year:
------------------------------------------------------------------------
Estimated annual Cumulative net
net revenue revenue
Fiscal year available for available for
repayment repayment
------------------------------------------------------------------------
2025.............................. $360,000 $360,000
2026.............................. 630,000 990,000
2027.............................. 4,000,000 4,990,000
2028.............................. 4,310,000 9,300,000
2029.............................. 4,460,000 13,760,000
2030.............................. 3,970,000 17,730,000
2031.............................. 4,150,000 21,880,000
2032.............................. 4,280,000 26,160,000
2033.............................. 4,430,000 30,590,000
2034.............................. 4,610,000 35,200,000
------------------------------------------------------------------------
The rates include a true-up of the capacity and energy rates based
on the variance of the actual cumulative net revenue available for
repayment from the planned cumulative net revenue available for
repayment in the table above. For every $100,000 under-recovery of the
planned cumulative net revenue available for repayment, Southeastern
will increase the base capacity charge by $0.02 per kilowatt per month,
up to a maximum of $0.75 per kilowatt per month, and increase the base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt per hour, to be implemented April 1 of the next
fiscal year. For every $100,000 over-recovery of the planned cumulative
net revenue available for repayment, Southeastern will reduce the
current base capacity charge by $0.02 per kilowatt per month, up to a
maximum of $0.75 per kilowatt per month but not below the initial base
capacity charge set in the rate filing, and reduce the current base
energy charge by 0.10 mills per kilowatt-hour, up to a maximum of 3.0
mills per kilowatt-hour but not below the initial base energy charge
set in the rate filing, to be implemented April 1 of the next fiscal
year. Southeastern will give written notice to the customers of the
amount of the true-up to the capacity and energy rates by February 1 of
the next fiscal year.
Additional rates for transmission and ancillary services provided
under this rate schedule shall be the rates charged Southeastern Power
Administration by the Virginia Power and DEP. Future adjustments to
these rates will become effective upon acceptance for filing by the
Federal Energy Regulatory Commission (FERC) of Virginia Power's or
DEP's rate.
Transmission: $7.53 per kilowatt of total contract demand per month
estimated as of March 2025, is presented for illustrative purposes.
Ancillary Services: 8.24 mills per kilowatt-hour of energy
estimated as of March 2025, is presented for illustrative purposes.
The initial charge for transmission and Ancillary Services will be
the Customer's ratable share of the charges for transmission,
distribution, and ancillary services paid by the Government. The
charges for transmission and ancillary services are governed by and
subject to refund based upon the determination in proceedings before
FERC involving the Company's or PJM's Open Access Transmission Tariff
(OATT).
Proceedings before FERC involving the OATT or the Distribution
charge may result in the separation of charges currently included in
the transmission rate. In this event, the Government may charge the
Customer for any and all separate transmission, ancillary services, and
distribution charges paid by the Government in behalf of the Customer.
These charges could be recovered through a capacity charge or an energy
charge, as determined by the Government.
Tandem Transmission Charge: $3.33 per kilowatt of total contract
demand per month, as an estimated cost as of March 2025.
The tandem transmission charge will recover the cost of
transmitting power from a project to the border of another transmitting
system. This rate will be a formulary rate based on the cost to the
Government for transmission of power from the Philpott project to the
border of the Virginia Electric and Power Company System and the cost
to the Government for transmission of power from the John H. Kerr
Project to the border of the Duke Energy Progress System. These charges
could be recovered through a capacity charge or an energy charge, as
determined by the Government.
Transmission and Ancillary Services: The charges for transmission
and ancillary services shall be governed by and subject to refund based
upon the determination in the proceeding involving the Virginian Power
or PJM's OATT.
Transmission, System Control, Reactive, and Regulation Services:
The charges for transmission and ancillary services shall be governed
by and subject to refund based upon the determination in the proceeding
involving Virginia Power's, DEP's, or PJM's OATT.
Contract Demand: The contract demand is the amount of capacity in
kilowatts stated in the contract which the Government is obligated to
supply and the Customer is entitled to receive.
Energy to be Furnished by the Government: The Government will sell
to the Customer and the Customer will purchase from the Government
energy each billing month equivalent to a percentage specified by
contract of the
[[Page 44681]]
energy made available to Virginia Power (less applicable losses). The
Customer's contract demand and accompanying energy will be allocated
proportionately to its individual delivery points served from the
Virginia Power's system. The applicable energy loss factor for
transmission is specified in the OATT.
These losses shall be effective until modified by FERC, pursuant to
application by the Company or PJM under Section 205 of the Federal
Power Act or Southeastern Power Administration under Section 206 of the
Federal Power Act or otherwise.
Billing Month: The billing month for power sold under this schedule
shall end at 12:00 midnight on the last day of each calendar month.
Wholesale Power Rate Schedule Replacement-2-D
Availability: This rate schedule shall be available to public
bodies and cooperatives (any one of whom is hereinafter called the
Customer) in North Carolina and Virginia to whom power is provided
pursuant to contracts between the Government and the customer from the
John H. Kerr and Philpott Projects (or Kerr-Philpott System).
Applicability: This rate schedule shall be applicable to the sale
of wholesale energy purchased to meet contract minimum energy and sold
under appropriate contracts between the Government and the Customer.
Character of Service: The energy supplied hereunder will be
delivered at the delivery points provided for under appropriate
contracts between the Government and the Customer.
Monthly Charge: The customer will pay its ratable share of
Southeastern's monthly cost for replacement energy. The ratable share
will be the cost allocation factor for the customer listed in the table
below times Southeastern's monthly cost for replacement energy
purchased for the Kerr-Philpott System, rounded to the nearest $0.01.
----------------------------------------------------------------------------------------------------------------
Capacity Cost allocation
Contract No. 89-00-1501- Customer allocation Average energy factor (%)
----------------------------------------------------------------------------------------------------------------
1230.............................. Albemarle EMC............ 2,593 7,265,195 1.5607720
1221.............................. B-A-R-C EC............... 3,740 10,478,931 2.2511750
853............................... Brunswick EMC............ 3,515 11,224,831 2.4114160
854............................... Carteret-Craven EMC...... 2,679 8,555,141 1.8378900
869............................... Carteret-Craven EMC 56 44,980 0.0096630
(Harkers Island).
855............................... Central EMC.............. 1,239 3,956,633 0.8499980
1220.............................. Central Virginia EC...... 7,956 22,291,834 4.7889250
1203.............................. City of Bedford.......... 1,200 938,157 0.2015430
1204.............................. City of Danville......... 5,600 4,378,067 0.9405340
895............................... City of Elizabeth City... 2,073 1,665,112 0.3577140
1215.............................. City of Franklin......... 1,003 782,530 0.1681100
878............................... City of Kinston.......... 1,466 1,177,546 0.2529710
880............................... City of Laurinburg....... 415 333,343 0.0716120
881............................... City of Lumberton........ 895 718,898 0.1544400
1205.............................. City of Martinsville..... 1,600 1,250,876 0.2687240
882............................... City of New Bern......... 1,204 967,098 0.2077600
1206.............................. City of Radford.......... 1,300 1,016,229 0.2183150
885............................... City of Rocky Mount...... 2,538 2,038,617 0.4379530
1208.............................. City of Salem............ 2,200 1,719,771 0.3694560
892............................... City of Washington....... 2,703 2,171,151 0.4664250
889............................... City of Wilson........... 2,950 2,369,550 0.5090470
1222.............................. Community EC............. 4,230 11,851,841 2.5461150
1211.............................. Craig-Botetourt EC....... 1,692 4,740,626 1.0184220
1231.............................. Edgecombe-Martin County 4,155 11,641,687 2.5009680
EMC.
875............................... Fayetteville Public Works 5,431 4,362,383 0.9371650
Commission.
856............................... Four County EMC.......... 4,198 13,405,929 2.8799780
891............................... Greenville Utilities 7,534 6,051,592 1.3000550
Commission.
857............................... Halifax EMC.............. 585 1,868,144 0.4013310
1232.............................. Halifax EMC.............. 2,021 5,662,529 1.2164730
1216.............................. Harrisonburg Electric 2,691 2,099,488 0.4510300
Commission.
858............................... Jones-Onslow EMC......... 5,184 16,554,630 3.5564090
859............................... Lumbee River EMC......... 3,729 11,908,221 2.5582270
1223.............................. Mecklenburg EMC.......... 11,344 31,784,224 6.8281630
1224.............................. Northern Neck EC......... 3,944 11,050,509 2.3739660
1225.............................. Northern Virginia EC..... 3,268 9,157,238 1.9672370
860............................... Pee Dee EMC.............. 2,968 9,478,037 2.0361540
861............................... Piedmont EMC............. 1,086 3,467,757 0.7449740
862............................... Pitt & Greene EMC........ 1,580 5,045,586 1.0839370
1226.............................. Prince George EC......... 2,530 7,088,689 1.5228540
863............................... Randolph EMC............. 3,608 11,521,818 2.4752170
1227.............................. Rappahannock EC.......... 22,427 62,837,164 13.4992270
1233.............................. Roanoke EMC.............. 5,528 15,488,635 3.3274030
1228.............................. Shenandoah Valley EMC.... 9,938 27,844,819 5.9818650
864............................... South River EMC.......... 6,119 19,540,468 4.1978530
1229.............................. Southside EC............. 14,575 40,837,012 8.7729610
865............................... Tideland EMC............. 680 2,171,517 0.4665040
1234.............................. Tideland EMC............. 2,418 6,774,859 1.4554340
870............................... Town of Apex............. 145 116,470 0.0250210
871............................... Town of Ayden............ 208 167,074 0.0358920
893............................... Town of Belhaven......... 182 146,189 0.0314060
872............................... Town of Benson........... 120 96,388 0.0207070
1212.............................. Town of Blackstone....... 389 303,494 0.0651990
[[Page 44682]]
873............................... Town of Clayton.......... 161 129,321 0.0277820
1213.............................. Town of Culpepper........ 391 305,054 0.0655340
894............................... Town of Edenton.......... 775 622,509 0.1337330
1214.............................. Town of Elkton........... 171 133,412 0.0286610
1218.............................. Town of Enfield.......... 259 202,085 0.0434140
874............................... Town of Farmville........ 237 190,368 0.0408960
876............................... Town of Fremont.......... 60 48,194 0.0103540
896............................... Town of Hamilton......... 40 32,129 0.0069020
897............................... Town of Hertford......... 203 163,057 0.0350290
898............................... Town of Hobgood.......... 46 36,949 0.0079380
877............................... Town of Hookerton........ 30 24,097 0.0051770
879............................... Town of La Grange........ 93 74,701 0.0160480
868............................... Town of Louisburg........ 857 2,736,773 0.5879370
883............................... Town of Pikeville........ 40 32,129 0.0069020
884............................... Town of Red Springs...... 117 93,979 0.0201890
1207.............................. Town of Richlands........ 500 390,899 0.0839760
899............................... Town of Robersonville.... 232 186,351 0.0400340
900............................... Town of Scotland Neck.... 304 244,184 0.0524580
886............................... Town of Selma............ 183 146,993 0.0315780
887............................... Town of Smithfield....... 378 303,624 0.0652270
901............................... Town of Tarboro.......... 2,145 1,722,945 0.3701380
888............................... Town of Wake Forest...... 149 119,682 0.0257110
1217.............................. Town of Wakefield........ 106 82,700 0.0177660
1219.............................. Town of Windsor.......... 331 258,243 0.0554780
866............................... Tri-County EMC........... 3,096 9,886,793 2.1239670
867............................... Wake EMC................. 2,164 6,910,536 1.4845810
--------------------------------------------------
Total......................... ......................... 196,500 465,487,218 100.0000000
----------------------------------------------------------------------------------------------------------------
Energy to be Furnished by the Government: The Government will sell
to the Customer and the Customer will purchase from the Government
energy each billing month equivalent to a percentage specified by
contract of the energy made available to the Facilitator (less any
losses required by the Facilitator). The customer's contract demand and
accompanying energy will be allocated proportionately to its individual
delivery points served from the Facilitator's system.
Billing Month: The billing month for power sold under this schedule
shall end at 12:00 midnight on the last day of each calendar month.
[FR Doc. 2025-17842 Filed 9-15-25; 8:45 am]
BILLING CODE 6450-01-P
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</html>Indexed from Federal Register on September 16, 2025.
This is legal information, not legal advice. Laws vary by jurisdiction and change frequently. Always verify current law with official sources and consult a licensed attorney in your jurisdiction for advice on your specific situation.