80 FR 57353 - Kerr-Philpott System
DEPARTMENT OF ENERGY
Southeastern Power Administration Federal Register Volume 80, Issue 184 (September 23, 2015)
Southeastern Power Administration
Federal Register Volume 80, Issue 184 (September 23, 2015)
| Page Range | 57353-57371 | |
| FR Document | 2015-24196 |
[Federal Register Volume 80, Number 184 (Wednesday, September 23, 2015)] [Notices] [Pages 57353-57371] From the Federal Register Online [www.thefederalregister.org] [FR Doc No: 2015-24196] ----------------------------------------------------------------------- DEPARTMENT OF ENERGY Southeastern Power Administration Kerr-Philpott System AGENCY: Southeastern Power Administration, (Southeastern), Department of Energy. ACTION: Notice of interim approval. ----------------------------------------------------------------------- SUMMARY: The Deputy Secretary, Department of Energy, confirmed and approved, on an interim basis new rate schedules VA-1-C, VA-2-C, VA-3- C, VA-4-C, DEP-1-C, DEP-2-C, DEP-3-C, DEP-4-C, AP-1-C, AP-2-C, AP-3-C, AP-4-C, NC-1-C, and Replacement-2-B. These rate schedules are applicable to Southeastern power sold to existing preference customers in the Virginia and North Carolina service area. The rate schedules are approved on an interim basis through September 30, 2020, and are subject to confirmation and approval by the Federal Energy Regulatory Commission (FERC) on a final basis. DATES: The rates are effective October 1, 2015. FOR FURTHER INFORMATION CONTACT: Virgil G. Hobbs III, Assistant Administrator, Finance and Marketing, Southeastern Power Administration, Department of Energy, 1166 Athens Tech Road, Elberton, Georgia 30635-4578, (706) 213-3800. SUPPLEMENTARY INFORMATION: The Federal Energy Regulatory Commission, by Order issued March 11, 2011, in Docket No. EF10-8-000 (134 FERC 62,233), confirmed and approved Wholesale Power Rate Schedules VA-1-B, VA-2-B, VA-3-B, VA-4-B, CP&L-1-B, CP&L-2-B, CP&L-3-B, CP&L-4-B, AP-1-B, AP-2-B, AP-3-B, AP-4-B, NC-1-B, and Replacement-2-A through September 30, 2015. This order replaces these rate schedules on an interim basis, subject to final approval by FERC. Dated: September 16, 2015. Elizabeth Sherwood-Randall, Deputy Secretary of Energy. Department of Energy Deputy Secretary In the Matter of: Southeastern Power Administration), Kerr-Philpott System Power Rates), Rate Order No. SEPA-58 Order Confirming and Approving Power Rates on an Interim Basis Pursuant to Sections 302(a) of the Department of Energy Organization Act, Public Law 95-91, the functions of the Secretary of the Interior and the Federal Power Commission under Section 5 of the Flood Control Act of 1944, 16 U.S.C. 825s, relating to the Southeastern Power Administration (Southeastern), were transferred to and vested in the Secretary of Energy. By Delegation Order No. 00-037.00A, effective December 6, 2001, the Secretary of Energy delegated to Southeastern's Administrator the authority to develop power and transmission rates, to the Deputy Secretary of Energy the authority to confirm, approve, and place in effect such rates on interim basis, and to the Federal Energy Regulatory Commission (FERC) the authority to confirm, approve, and place into effect on a final basis or to disapprove rates developed by the Administrator under the delegation. This rate is issued by the Deputy Secretary pursuant to that delegation order. Background Power from the Kerr-Philpott Projects is presently sold under Wholesale [[Page 57354]] Power Rate Schedules VA-1-B, VA-2-B, VA-3-B, VA-4-B, CP&L-1-B, CP&L-2- B, CP&L-3-B, CP&L-4-B, AP-1-B, AP-2-B, AP-3-B, AP-4-B, NC-1-B, and Replacement-2-A. These rate schedules were approved by the FERC on March 11, 2011, for a period ending September 30, 2015 (134 FERC 62,233). Public Notice and Comment Notice of a proposed rate adjustment for the Kerr-Philpott System was published in the Federal Register (80 FR 12819) on March 11, 2015. The notice advised interested parties that a public information and comment forum would be held in Boydton, Virginia on April 21, 2015. Written comments were due on or before June 9, 2015. The proposed rate adjustment was a reduction of about six percent (6%). Subsequent to the Public Information and Comment Forum on April 21, Southeastern discovered an error due to omissions in the repayment study used to develop the proposed rate schedules. Two accounting lines were omitted from the estimated Corps O&M expenses included in the study. The accounting lines were Work Category Code 602, Operation for Flood Damage Reduction, and Work Category Code 612, Maintenance for Flood Damage Reduction. On June 1, 2015, Southeastern sent a letter to all Kerr-Philpott customers notifying them of the error and notifying them Southeastern intended to add the omitted accounting lines and correct the error in the rate schedules Southeastern would recommend to the Deputy Secretary. After these corrections, the proposed rate is an increase of about 2.2 percent. Southeastern received comments from one source, the Southeast Federal Power Customers, Inc., as a result of the above notifications. The comments and Southeastern's response are below. Comment: The SeFPC questions whether the expenses in accounts WCC 602 and 612 should properly be assigned to hydropower as a joint expense. Given the Congressional Mandate to provide flood control at the Kerr and Philpott projects, the assignment of these costs appears to be arbitrary, capricious, and not consistent with the authorizing statutes. The SeFPC would ask SEPA to review the inclusion of these costs and work with Corps representatives to remove such expenses as joint expense for purpose of the proposed rate. Failure to take this action would impose over $10 million in additional cost for the hydropower customers over the five year study period in the repayment study which should properly be borne by the flood control purpose. The referenced Work Category Codes 602 and 612 contain operation and maintenance expenses associated with flood risk management. The Corps has taken the position the John H. Kerr and Philpott final cost allocations state that the only specific costs at these reservoirs are Power and Recreation, and that as a result, the Corps cannot charge costs to the flood control purpose at these projects. The $10 million assigned to hydropower and disputed by SeFPC include the operations, maintenance and readiness of equipment associated with spillways, sluices, pumping plants and earthen dams. The Corps has included these costs in the O&M expenses included in the financial statements provided to Southeastern for the John H. Kerr and Philpott projects. SeFPC has raised legitimate questions about the nature and assignment of WCC s 602 and 612. Further study of this issue is necessary. Southeastern will continue to discuss with the Corps the appropriateness of assigning these costs solely to hydropower. Southeastern and the Corps have discussed the need for a new authorized purpose allocation study and agreed to jointly fund the effort. Once completed, Southeastern and the Corps will work together to determine whether costs in these accounts should be allocated to purposes other than Power and Recreation. A reallocation could significantly reduce the proportion of charges assigned to Southeastern's power customers and ensure that costs are being assigned to appropriate cost-causers. Discussion System Repayment An examination of Southeastern's revised system power repayment study, prepared in July 2015, for the Kerr-Philpott System shows that with the proposed rates, all system power costs are paid within the appropriate repayment period required by existing law and DOE Procedure RA 6120.2. The Administrator of Southeastern Power Administration has certified that the rates are consistent with applicable law and that they are the lowest possible rates to customers consistent with sound business principles, pursuant to section 5 of the Flood Control Act (16 U.S.C.A.835(s)). Environmental Impact Southeastern has reviewed the possible environmental impacts of the rate adjustment under consideration and has concluded that, because the adjusted rates would not significantly affect the quality of the human environment within the meaning of the National Environmental Policy Act of 1969 (42 U.S.C.A 4332), the proposed action is not a major Federal action for which preparation of an Environmental Impact Statement is required. Availability of Information Information regarding these rates, including studies and other supporting materials and transcripts of the public information and comment forum, is available for public review in the offices of Southeastern Power Administration, 1166 Athens Tech Road, Elberton, Georgia 30635, and in the Power Marketing Liaison Office, James Forrestal Building, 1000 Independence Avenue SW., Washington, DC 20585. Order In view of the foregoing and pursuant to the authority delegated to me by the Secretary of Energy, I hereby confirm and approve on an interim basis, effective October 1, 2015, attached Wholesale Power Rate Schedules VA-1-C, VA-2-C, VA-3-C, VA-4-C, DEP-1-C, DEP-2-C, DEP-3-C, DEP-4-C, AP-1-C, AP-2-C, AP-3-C, AP-4-C, NC-1-C, and Replacement-2-B. The Rate Schedules shall remain in effect on an interim basis through September 30, 2020, unless such period is extended or until the FERC confirms and approves them or substitutes Rate Schedules on a final basis. Dated: September 16, 2015. Elizabeth Sherwood-Randall Deputy Secretary of Energy Wholesale Power Rate Schedule VA-1-C 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: [[Page 57355]] 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: $4.40 per kilowatt of total contract demand per month. Initial Base Energy Charge: 17.80 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 net revenue Cumulative net Fiscal year available for revenue available repayment for repayment ------------------------------------------------------------------------ 2015.............................. $490,000 $490,000 2016.............................. $2,730,000 $3,220,000 2017.............................. $2,420,000 $5,640,000 2018.............................. $1,910,000 $7,550,000 2019.............................. $1,910,000 $9,460,000 2020.............................. $2,010,000 $11,470,000 2021.............................. $2,110,000 $13,580,000 2022.............................. $2,190,000 $15,770,000 2023.............................. $2,290,000 $18,060,000 2024.............................. $2,400,000 $20,460,000 ------------------------------------------------------------------------ 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 of over-recovery of the planned cumulative net revenue available for repayment, Southeastern will reduce the base capacity charge by $0.02 per kilowatt per month, up to a maximum of $0.75 per kilowatt per month, and reduce 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. 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: $0.775 per kilowatt of total contract demand per month estimated as of April 2015, is presented for illustrative purposes. Ancillary Services: 0.34 mills per kilowatt-hour of energy estimated as of April 2015, 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 the 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: $0.42 per kilowatt of total contract demand per month, as an estimated cost as of April 2015. 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 [[Page 57356]] 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 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-C 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: $4.40 per kilowatt of total contract demand per month. Initial Base Energy Charge: 17.80 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 net revenue Cumulative net Fiscal year available for revenue available repayment for repayment ------------------------------------------------------------------------ 2015.............................. $490,000 $490,000 2016.............................. 2,730,000 3,220,000 2017.............................. 2,420,000 5,640,000 2018.............................. 1,910,000 7,550,000 2019.............................. 1,910,000 9,460,000 2020.............................. 2,010,000 11,470,000 2021.............................. 2,110,000 13,580,000 2022.............................. 2,190,000 15,770,000 2023.............................. 2,290,000 18,060,000 2024.............................. 2,400,000 20,460,000 ------------------------------------------------------------------------ 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 of over-recovery of the planned cumulative net revenue available for repayment, Southeastern will reduce the base capacity charge by $0.02 per kilowatt per month, up to a maximum of $0.75 per kilowatt per month, and reduce 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. 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: $0.775 per kilowatt of total contract demand per month estimated as of April 2015, is presented for illustrative purposes. Ancillary Services: 0.34 mills per kilowatt-hour of energy estimated as of April 2015, 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 the 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 [[Page 57357]] 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: $0.42 per kilowatt of total contract demand per month, as an estimated cost as of April 2015. 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-C 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: $4.40 per kilowatt of total contract demand per month. Initial Base Energy Charge: 17.80 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 net revenue Cumulative net Fiscal year available for revenue available repayment for repayment ------------------------------------------------------------------------ 2015.............................. $490,000 $490,000 2016.............................. 2,730,000 3,220,000 2017.............................. 2,420,000 5,640,000 2018.............................. 1,910,000 7,550,000 2019.............................. 1,910,000 9,460,000 2020.............................. 2,010,000 11,470,000 2021.............................. 2,110,000 13,580,000 2022.............................. 2,190,000 15,770,000 2023.............................. 2,290,000 18,060,000 2024.............................. 2,400,000 20,460,000 ------------------------------------------------------------------------ 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 of over-recovery of the planned cumulative net revenue available for repayment, Southeastern will reduce the base [[Page 57358]] capacity charge by $0.02 per kilowatt per month, up to a maximum of $0.75 per kilowatt per month, and reduce 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. 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: 0.34 mills per kilowatt-hour of energy estimated as of April 2015, 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 the 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: $0.42 per kilowatt of total contract demand per month, as an estimated cost as of April 2015. 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-C 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: $4.40 per kilowatt of total contract demand per month. Initial Base Energy Charge: 17.80 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 net revenue Cumulative net Fiscal year available for revenue available repayment for repayment ------------------------------------------------------------------------ 2015.............................. $490,000 $490,000 2016.............................. 2,730,000 3,220,000 2017.............................. 2,420,000 5,640,000 [[Page 57359]] 2018.............................. 1,910,000 7,550,000 2019.............................. 1,910,000 9,460,000 2020.............................. 2,010,000 11,470,000 2021.............................. 2,110,000 13,580,000 2022.............................. 2,190,000 15,770,000 2023.............................. 2,290,000 18,060,000 2024.............................. 2,400,000 20,460,000 ------------------------------------------------------------------------ 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 of over-recovery of the planned cumulative net revenue available for repayment, Southeastern will reduce the base capacity charge by $0.02 per kilowatt per month, up to a maximum of $0.75 per kilowatt per month, and reduce 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. 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: 0.34 mills per kilowatt-hour of energy estimated as of April 2015, 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 the 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: $0.42 per kilowatt of total contract demand per month, as an estimated cost as of April 2015. 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 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-C 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: [[Page 57360]] 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: $4.40 per kilowatt of total contract demand per month. Initial Base Energy Charge: 17.80 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 net revenue Cumulative net Fiscal year available for revenue available repayment for repayment ------------------------------------------------------------------------ 2015.............................. $490,000 $490,000 2016.............................. 2,730,000 3,220,000 2017.............................. 2,420,000 5,640,000 2018.............................. 1,910,000 7,550,000 2019.............................. 1,910,000 9,460,000 2020.............................. 2,010,000 11,470,000 2021.............................. 2,110,000 13,580,000 2022.............................. 2,190,000 15,770,000 2023.............................. 2,290,000 18,060,000 2024.............................. 2,400,000 20,460,000 ------------------------------------------------------------------------ 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 of over-recovery of the planned cumulative net revenue available for repayment, Southeastern will reduce the base capacity charge by $0.02 per kilowatt per month, up to a maximum of $0.75 per kilowatt per month, and reduce 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. 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: $1.546 per kilowatt of total contract demand per month as of April 2015, 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 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: $0.42 per kilowatt of total contract demand per month, as an estimated cost as of April 2015. 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. [[Page 57361]] Wholesale Power Rate Schedule DEP-2-C 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: $4.40 per kilowatt of total contract demand per month. Initial Base Energy Charge: 17.80 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 net revenue Cumulative net Fiscal year available for revenue available repayment for repayment ------------------------------------------------------------------------ 2015.............................. $490,000 $490,000 2016.............................. 2,730,000 3,220,000 2017.............................. 2,420,000 5,640,000 2018.............................. 1,910,000 7,550,000 2019.............................. 1,910,000 9,460,000 2020.............................. 2,010,000 11,470,000 2021.............................. 2,110,000 13,580,000 2022.............................. 2,190,000 15,770,000 2023.............................. 2,290,000 18,060,000 2024.............................. 2,400,000 20,460,000 ------------------------------------------------------------------------ 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 of over-recovery of the planned cumulative net revenue available for repayment, Southeastern will reduce the base capacity charge by $0.02 per kilowatt per month, up to a maximum of $0.75 per kilowatt per month, and reduce 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. 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: $1.546 per kilowatt of total contract demand per month as of April 2015, 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 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: $0.42 per kilowatt of total contract demand per month, as an estimated cost as of April 2015. 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. [[Page 57362]] 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-C 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: $4.40 per kilowatt of total contract demand per month. Initial Base Energy Charge: 17.80 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 net revenue Cumulative net Fiscal year available for revenue available repayment for repayment ------------------------------------------------------------------------ 2015.............................. $490,000 $490,000 2016.............................. 2,730,000 3,220,000 2017.............................. 2,420,000 5,640,000 2018.............................. 1,910,000 7,550,000 2019.............................. 1,910,000 9,460,000 2020.............................. 2,010,000 11,470,000 2021.............................. 2,110,000 13,580,000 2022.............................. 2,190,000 15,770,000 2023.............................. 2,290,000 18,060,000 2024.............................. 2,400,000 20,460,000 ------------------------------------------------------------------------ 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 of over-recovery of the planned cumulative net revenue available for repayment, Southeastern will reduce the base capacity charge by $0.02 per kilowatt per month, up to a maximum of $0.75 per kilowatt per month, and reduce 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. 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 in behalf of the Customer. Tandem Transmission Charge: $0.42 per kilowatt of total contract demand per month, as an estimated cost as of April 2015. 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 [[Page 57363]] 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-4-C 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: $4.40 per kilowatt of total contract demand per month. Initial Base Energy Charge: 17.80 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 net revenue Cumulative net Fiscal year available for revenue available repayment for repayment ------------------------------------------------------------------------ 2015.............................. $490,000 $490,000 2016.............................. 2,730,000 3,220,000 2017.............................. 2,420,000 5,640,000 2018.............................. 1,910,000 7,550,000 2019.............................. 1,910,000 9,460,000 2020.............................. 2,010,000 11,470,000 2021.............................. 2,110,000 13,580,000 2022.............................. 2,190,000 15,770,000 2023.............................. 2,290,000 18,060,000 2024.............................. 2,400,000 20,460,000 ------------------------------------------------------------------------ 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 of over-recovery of the planned cumulative net revenue available for repayment, Southeastern will reduce the base capacity charge by $0.02 per kilowatt per month, up to a maximum of $0.75 per kilowatt per month, and reduce 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. 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. Tandem Transmission Charge: $0.42 per kilowatt of total contract demand per month, as an estimated cost as of April 2015. 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 [[Page 57364]] 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-C 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 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: $4.40 per kilowatt of total contract demand per month. Initial Base Energy Charge: 17.80 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 net revenue Cumulative net Fiscal year available for revenue available repayment for repayment ------------------------------------------------------------------------ 2015.............................. $490,000 $490,000 2016.............................. 2,730,000 3,220,000 2017.............................. 2,420,000 5,640,000 2018.............................. 1,910,000 7,550,000 2019.............................. 1,910,000 9,460,000 2020.............................. 2,010,000 11,470,000 2021.............................. 2,110,000 13,580,000 2022.............................. 2,190,000 15,770,000 2023.............................. 2,290,000 18,060,000 2024.............................. 2,400,000 20,460,000 ------------------------------------------------------------------------ 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 of over-recovery of the planned cumulative net revenue available for repayment, Southeastern will reduce the base capacity charge by $0.02 per kilowatt per month, up to a maximum of $0.75 per kilowatt per month, and reduce 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. 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: $0.775 per kilowatt of total contract demand per month estimated as of April 2015, is a presented for illustrative purposes. Ancillary Services: 0.34 mills per kilowatt-hour of energy estimated as of April 2015, 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 [[Page 57365]] governed by and subject to refund based upon the determination in proceedings before the 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: $0.42 per kilowatt of total contract demand per month, as an estimated cost as of April 2015. 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). 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 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-2-C 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: $4.40 per kilowatt of total contract demand per month. Initial Base Energy Charge: 17.80 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 net revenue Cumulative net Fiscal year available for revenue available repayment for repayment ------------------------------------------------------------------------ 2015.............................. $490,000 $490,000 2016.............................. 2,730,000 3,220,000 2017.............................. 2,420,000 5,640,000 2018.............................. 1,910,000 7,550,000 2019.............................. 1,910,000 9,460,000 2020.............................. 2,010,000 11,470,000 2021.............................. 2,110,000 13,580,000 2022.............................. 2,190,000 15,770,000 2023.............................. 2,290,000 18,060,000 2024.............................. 2,400,000 20,460,000 ------------------------------------------------------------------------ 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 [[Page 57366]] 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 of over-recovery of the planned cumulative net revenue available for repayment, Southeastern will reduce the base capacity charge by $0.02 per kilowatt per month, up to a maximum of $0.75 per kilowatt per month, and reduce 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. 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: $0.775 per kilowatt of total contract demand per month estimated as of April 2015, is presented for illustrative purposes. Ancillary Services: 0.34 mills per kilowatt-hour of energy estimated as of April 2015, 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 the 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: $0.42 per kilowatt of total contract demand per month, as an estimated cost as of April 2015 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 Charges: 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). 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 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-C 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: $4.40 per kilowatt of total contract demand per month. Initial Base Energy Charge: 17.80 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: [[Page 57367]] ------------------------------------------------------------------------ Estimated annual net revenue Cumulative net Fiscal year available for revenue available repayment for repayment ------------------------------------------------------------------------ 2015.............................. $490,000 $490,000 2016.............................. 2,730,000 3,220,000 2017.............................. 2,420,000 5,640,000 2018.............................. 1,910,000 7,550,000 2019.............................. 1,910,000 9,460,000 2020.............................. 2,010,000 11,470,000 2021.............................. 2,110,000 13,580,000 2022.............................. 2,190,000 15,770,000 2023.............................. 2,290,000 18,060,000 2024.............................. 2,400,000 20,460,000 ------------------------------------------------------------------------ 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 of over-recovery of the planned cumulative net revenue available for repayment, Southeastern will reduce the base capacity charge by $0.02 per kilowatt per month, up to a maximum of $0.75 per kilowatt per month, and reduce 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. 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: 0.34 mills per kilowatt-hour of energy estimated as of April 2015, 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 the 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: $0.42 per kilowatt of total contract demand per month, as an estimated cost as of April 2015. 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 Charges: 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). 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 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-C 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 [[Page 57368]] 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: $4.40 per kilowatt of total contract demand per month. Initial Base Energy Charge: 17.80 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 net revenue Cumulative net Fiscal year available for revenue available repayment for repayment ------------------------------------------------------------------------ 2015.............................. $490,000 $490,000 2016.............................. 2,730,000 3,220,000 2017.............................. 2,420,000 5,640,000 2018.............................. 1,910,000 7,550,000 2019.............................. 1,910,000 9,460,000 2020.............................. 2,010,000 11,470,000 2021.............................. 2,110,000 13,580,000 2022.............................. 2,190,000 15,770,000 2023.............................. 2,290,000 18,060,000 2024.............................. 2,400,000 20,460,000 ------------------------------------------------------------------------ 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 of over-recovery of the planned cumulative net revenue available for repayment, Southeastern will reduce the base capacity charge by $0.02 per kilowatt per month, up to a maximum of $0.75 per kilowatt per month, and reduce 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. 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: 0.34 mills per kilowatt-hour of energy estimated as of April 2015, 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 the 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: $0.42 per kilowatt of total contract demand per month, as an estimated cost as of April 2015. 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 Charges: 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). 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 [[Page 57369]] 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 NC-1-C 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: $4.40 per kilowatt of total contract demand per month. Initial Base Energy Charge: 17.80 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 net revenue Cumulative net Fiscal year available for revenue available repayment for repayment ------------------------------------------------------------------------ 2015.............................. $490,000 $490,000 2016.............................. 2,730,000 3,220,000 2017.............................. 2,420,000 5,640,000 2018.............................. 1,910,000 7,550,000 2019.............................. 1,910,000 9,460,000 2020.............................. 2,010,000 11,470,000 2021.............................. 2,110,000 13,580,000 2022.............................. 2,190,000 15,770,000 2023.............................. 2,290,000 18,060,000 2024.............................. 2,400,000 20,460,000 ------------------------------------------------------------------------ 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 of over-recovery of the planned cumulative net revenue available for repayment, Southeastern will reduce the base capacity charge by $0.02 per kilowatt per month, up to a maximum of $0.75 per kilowatt per month, and reduce 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. 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: $0.775 per kilowatt of total contract demand per month estimated as of April 2015, is presented for illustrative purposes. Ancillary Services: 0.34 mills per kilowatt-hour of energy estimated as of April 2015, 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 the 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 [[Page 57370]] 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: $0.42 per kilowatt of total contract demand per month, as an estimated cost as of April 2015. 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 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 the 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-B 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. ---------------------------------------------------------------------------------------------------------------- Cost Contract No. 89-00-1501- Customer Capacity Average energy allocation allocation factor ---------------------------------------------------------------------------------------------------------------- 1230............................... Albemarle EMC.............. 2,593 6,950,707 1.565921% 1221............................... B-A-R-C EC................. 3,740 10,060,472 2.266518% 853................................ Brunswick EMC.............. 3,515 10,468,686 2.358485% 854................................ Carteret-Craven EMC........ 2,679 7,978,836 1.797548% 869................................ Carteret-Craven EMC........ 56 42,281 0.009525% 855................................ Central EMC................ 1,239 3,690,100 0.831341% 1220............................... Central Virginia EC........ 7,956 21,534,960 4.851599% 1203............................... City of Bedford............ 1,200 906,166 0.204150% 1204............................... City of Danville........... 5,600 4,228,775 0.952698% 895................................ City of Elizabeth City..... 2,073 1,565,205 0.352624% 1215............................... City of Franklin........... 1,003 754,359 0.169949% 878................................ City of Kinston............ 1,466 1,106,893 0.249371% 880................................ City of Laurinburg......... 415 313,343 0.070593% 881................................ City of Lumberton.......... 895 675,764 0.152242% 1205............................... City of Martinsville....... 1,600 1,208,222 0.272200% 882................................ City of New Bern........... 1,204 909,072 0.204804% 1206............................... City of Radford............ 1,300 981,575 0.221138% 885................................ City of Rocky Mount........ 2,538 1,916,300 0.431722% 1208............................... City of Salem.............. 2,200 1,661,127 0.374234% 892................................ City of Washington......... 2,703 2,040,882 0.459789% 889................................ City of Wilson............. 2,950 2,227,377 0.501805% 1222............................... Community EC............... 4,230 11,394,466 2.567053% 1211............................... Craig-Botetourt EC......... 1,692 4,575,816 1.030883% 1231............................... Edgecombe-Martin County EMC 4,155 11,275,547 2.540262% 875................................ Fayetteville Public Works 5,431 4,100,640 0.923831% Commission. 856................................ Four County EMC............ 4,198 12,502,857 2.816762% 891................................ Greenville Utilities 7,534 5,688,496 1.281558% Commission. 857................................ Halifax EMC................ 585 1,742,299 0.392522% 1232............................... Halifax EMC................ 2,021 5,478,308 1.234205% 1216............................... Harrisonburg Electric 2,691 2,050,360 0.461924% Commission. 858................................ Jones-Onslow EMC........... 5,184 15,439,450 3.478345% 859................................ Lumbee River EMC........... 3,729 11,106,040 2.502074% [[Page 57371]] 1223............................... Mecklenburg EMC............ 11,344 30,806,162 6.940303% 1224............................... Northern Neck EC........... 3,944 10,572,278 2.381823% 1225............................... Northern Virginia EC....... 3,268 8,875,341 1.999521% 860................................ Pee Dee EMC................ 2,968 8,839,562 1.991460% 861................................ Piedmont EMC............... 1,086 3,234,540 0.728708% 862................................ Pitt & Greene EMC.......... 1,580 4,705,697 1.060144% 1226............................... Prince George EC........... 2,530 6,781,913 1.527893% 863................................ Randolph EMC............... 3,608 10,745,666 2.420885% 1227............................... Rappahannock EC............ 22,427 60,450,624 13.618889% 1233............................... Roanoke EMC................ 5,528 14,904,403 3.357805% 1228............................... Shenandoah Valley EMC...... 9,938 26,943,520 6.070091% 864................................ South River EMC............ 6,119 18,224,150 4.105709% 1229............................... Southside EC............... 14,575 39,381,017 8.872128% 865................................ Tideland EMC............... 680 2,025,236 0.456264% 1234............................... Tideland EMC............... 2,418 6,554,050 1.476558% 870................................ Town of Apex............... 145 109,482 0.024665% 871................................ Town of Ayden.............. 208 157,049 0.035381% 893................................ Town of Belhaven........... 182 137,418 0.030959% 872................................ Town of Benson............. 120 90,605 0.020412% 1212............................... Town of Blackstone......... 389 292,568 0.065912% 873................................ Town of Clayton............ 161 121,562 0.027387% 1213............................... Town of Culpepper.......... 391 297,916 0.067117% 894................................ Town of Edenton............ 775 585,159 0.131830% 1214............................... Town of Elkton............. 171 128,609 0.028974% 1218............................... Town of Enfield............ 259 194,810 0.043889% 874................................ Town of Farmville.......... 237 178,946 0.040315% 876................................ Town of Fremont............ 60 45,303 0.010206% 896................................ Town of Hamilton........... 40 30,202 0.006804% 897................................ Town of Hertford........... 203 153,274 0.034531% 898................................ Town of Hobgood............ 46 34,732 0.007825% 877................................ Town of Hookerton.......... 30 22,651 0.005103% 879................................ Town of La Grange.......... 93 70,219 0.015820% 868................................ Town of Louisburg.......... 857 2,552,452 0.575041% 883................................ Town of Pikeville.......... 40 30,202 0.006804% 884................................ Town of Red Springs........ 117 88,340 0.019902% 1207............................... Town of Richlands.......... 500 377,569 0.085062% 899................................ Town of Robersonville...... 232 175,170 0.039464% 900................................ Town of Scotland Neck...... 304 229,533 0.051711% 886................................ Town of Selma.............. 183 138,173 0.031129% 887................................ Town of Smithfield......... 378 285,407 0.064299% 901................................ Town of Tarboro............ 2,145 1,619,568 0.364872% 888................................ Town of Wake Forest........ 149 112,501 0.025345% 1217............................... Town of Wakefield.......... 106 79,723 0.017961% 1219............................... Town of Windsor............ 331 248,946 0.056085% 866................................ Tri-County EMC............. 3,096 9,220,782 2.077345% 867................................ Wake EMC................... 2,164 6,445,017 1.451994% ---------------------------------------------------------------------------- Total.......................... ........................... 196,500 443,873,428 .............. ---------------------------------------------------------------------------------------------------------------- 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. 2015-24196 Filed 9-22-15; 8:45 am] BILLING CODE 6450-01-P
![Federal Register / Vol. 80, No. 184 / Wednesday, September 23, 2015 / Notices 57353
(C) provide the lowest possible rates into effect subject to refund with and approval by the Federal Energy
to consumers consistent with sound interest; the Commission may order Regulatory Commission (FERC) on a
business principles. refunds with interest if the Commission final basis.
10. Unlike the Commission’s statutory later determines in its final decision not DATES: The rates are effective October 1,
authority under the Federal Power Act, to approve the rates.27 2015.
the Commission’s authority under 13. In addition, we will provide an FOR FURTHER INFORMATION CONTACT:
sections 7(a) and 7(k) of the Northwest additional period of time for parties to Virgil G. Hobbs III, Assistant
Power Act does not include the power file comments and reply comments on Administrator, Finance and Marketing,
to modify the rates. The responsibility issues related to final confirmation and Southeastern Power Administration,
for developing rates in the first instance approval of Bonneville’s proposed rates. Department of Energy, 1166 Athens
is vested with Bonneville’s This will ensure that the record in this Tech Road, Elberton, Georgia 30635–
Administrator. The rates are then proceeding is complete and fully 4578, (706) 213–3800.
submitted to the Commission for developed.
The Commission orders: SUPPLEMENTARY INFORMATION: The
approval or disapproval. In this regard,
(A) Interim approval of Bonneville’s Federal Energy Regulatory Commission,
the Commission’s role can be viewed as
proposed wholesale power and by Order issued March 11, 2011, in
an appellate one: to affirm or remand
transmission rates is hereby granted, to Docket No. EF10–8–000 (134 FERC
the rates submitted to it for review.23
become effective on October 1, 2015, 62,233), confirmed and approved
11. Moreover, review at this interim
through September 30, 2017, subject to Wholesale Power Rate Schedules VA–1–
stage is further limited. In view of the
refund with interest as set forth in B, VA–2–B, VA–3–B, VA–4–B, CP&L–1–
volume and complexity of a Bonneville
section 300.20(c) of the Commission’s B, CP&L–2–B, CP&L–3–B, CP&L–4–B,
rate application, such as the one now
regulations 28 pending final action and AP–1–B, AP–2–B, AP–3–B, AP–4–B,
before the Commission in this filing,
either their approval or disapproval. NC–1–B, and Replacement–2–A through
and the limited period in advance of the
(B) Within thirty (30) days of the date September 30, 2015. This order replaces
requested effective date in which to
of this order, parties who wish to do so these rate schedules on an interim basis,
review the application,24 the
may file additional comments regarding subject to final approval by FERC.
Commission generally defers resolution
of issues on the merits of Bonneville’s final confirmation and approval of Dated: September 16, 2015.
application until the order on final Bonneville’s proposed rates. Parties who Elizabeth Sherwood-Randall,
confirmation. Thus, the proposed rates, wish to do so may file reply comments Deputy Secretary of Energy.
if not patently deficient, generally are within twenty (20) days thereafter.
(C) The Secretary shall promptly Department of Energy
approved on an interim basis and the
parties are afforded an additional publish this order in the Federal Deputy Secretary
opportunity in which to raise issues Register.
In the Matter of: Southeastern Power
with regard to Bonneville’s filing.25 By the Commission.
Administration), Kerr-Philpott System
12. The Commission declines at this Issued: September 17, 2015. Power Rates), Rate Order No. SEPA–58
time to grant final confirmation and Nathaniel J. Davis, Sr.,
approval of Bonneville’s proposed Deputy Secretary. Order Confirming and Approving
wholesale power and transmission rates. Power Rates on an Interim Basis
[FR Doc. 2015–24136 Filed 9–22–15; 8:45 am]
The Commission’s preliminary review Pursuant to Sections 302(a) of the
BILLING CODE 6717–01–P
nevertheless indicates that Bonneville’s Department of Energy Organization Act,
wholesale power and transmission rates Public Law 95–91, the functions of the
filing appears to meet the statutory DEPARTMENT OF ENERGY Secretary of the Interior and the Federal
standards and the minimum threshold Power Commission under Section 5 of
filing requirements of Part 300 of the Southeastern Power Administration the Flood Control Act of 1944, 16 U.S.C.
Commission’s regulations.26 Moreover, 825s, relating to the Southeastern Power
the Commission’s preliminary review of Kerr-Philpott System Administration (Southeastern), were
Bonneville’s submittal indicates that it transferred to and vested in the
AGENCY: Southeastern Power
does not contain any patent Secretary of Energy. By Delegation
Administration, (Southeastern),
deficiencies. The proposed rates Order No. 00–037.00A, effective
Department of Energy.
therefore will be approved on an interim December 6, 2001, the Secretary of
basis pending our further review. We ACTION: Notice of interim approval.
Energy delegated to Southeastern’s
note, as well, that no one will be SUMMARY: The Deputy Secretary, Administrator the authority to develop
harmed by this decision because interim Department of Energy, confirmed and power and transmission rates, to the
approval allows Bonneville’s rates to go approved, on an interim basis new rate Deputy Secretary of Energy the
23 See, e.g., United States Department of Energy—
schedules VA–1–C, VA–2–C, VA–3–C, authority to confirm, approve, and place
Bonneville Power Admin., 67 FERC ¶ 61,351, at VA–4–C, DEP–1–C, DEP–2–C, DEP–3–C, in effect such rates on interim basis, and
62,216–17 (1994); see also, e.g., Aluminum Co. of DEP–4–C, AP–1–C, AP–2–C, AP–3–C, to the Federal Energy Regulatory
America v. Bonneville Power Admin., 903 F.2d 585, AP–4–C, NC–1–C, and Replacement–2– Commission (FERC) the authority to
592–93 (9th Cir. 1989). B. These rate schedules are applicable to confirm, approve, and place into effect
24 See 18 CFR 300.10(a)(3)(ii) (2015).
25 See, e.g., United States Department of Energy—
Southeastern power sold to existing on a final basis or to disapprove rates
mstockstill on DSK4VPTVN1PROD with NOTICES
Bonneville Power Administration, 64 FERC ¶ preference customers in the Virginia developed by the Administrator under
61,375, at 63,606 (1993); United States Department and North Carolina service area. The the delegation. This rate is issued by the
of Energy—Bonneville Power Admin., 40 FERC ¶ rate schedules are approved on an Deputy Secretary pursuant to that
61,351, at 62,059–60 (1987). interim basis through September 30, delegation order.
26 See, e.g., United States Department of Energy—
2020, and are subject to confirmation
Bonneville Power Admin., 105 FERC ¶ 61,006, at PP Background
13–14 (2003); United States Department of Energy—
Bonneville Power Admin., 96 FERC ¶ 61,360, at 27 See 18 CFR 300.20(c) (2015). Power from the Kerr-Philpott Projects
62,358 (2001). 28 18 CFR 300.20(c) (2015). is presently sold under Wholesale
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![Federal Register / Vol. 80, No. 184 / Wednesday, September 23, 2015 / Notices 57371
Capacity Average Cost allocation
Contract No. 89-00-1501- Customer allocation energy factor
1223 ........................................ Mecklenburg EMC .................................................................. 11,344 30,806,162 6.940303%
1224 ........................................ Northern Neck EC .................................................................. 3,944 10,572,278 2.381823%
1225 ........................................ Northern Virginia EC .............................................................. 3,268 8,875,341 1.999521%
860 .......................................... Pee Dee EMC ........................................................................ 2,968 8,839,562 1.991460%
861 .......................................... Piedmont EMC ....................................................................... 1,086 3,234,540 0.728708%
862 .......................................... Pitt & Greene EMC ................................................................ 1,580 4,705,697 1.060144%
1226 ........................................ Prince George EC .................................................................. 2,530 6,781,913 1.527893%
863 .......................................... Randolph EMC ....................................................................... 3,608 10,745,666 2.420885%
1227 ........................................ Rappahannock EC ................................................................. 22,427 60,450,624 13.618889%
1233 ........................................ Roanoke EMC ........................................................................ 5,528 14,904,403 3.357805%
1228 ........................................ Shenandoah Valley EMC ....................................................... 9,938 26,943,520 6.070091%
864 .......................................... South River EMC ................................................................... 6,119 18,224,150 4.105709%
1229 ........................................ Southside EC ......................................................................... 14,575 39,381,017 8.872128%
865 .......................................... Tideland EMC ......................................................................... 680 2,025,236 0.456264%
1234 ........................................ Tideland EMC ......................................................................... 2,418 6,554,050 1.476558%
870 .......................................... Town of Apex ......................................................................... 145 109,482 0.024665%
871 .......................................... Town of Ayden ....................................................................... 208 157,049 0.035381%
893 .......................................... Town of Belhaven .................................................................. 182 137,418 0.030959%
872 .......................................... Town of Benson ..................................................................... 120 90,605 0.020412%
1212 ........................................ Town of Blackstone ................................................................ 389 292,568 0.065912%
873 .......................................... Town of Clayton ..................................................................... 161 121,562 0.027387%
1213 ........................................ Town of Culpepper ................................................................. 391 297,916 0.067117%
894 .......................................... Town of Edenton .................................................................... 775 585,159 0.131830%
1214 ........................................ Town of Elkton ....................................................................... 171 128,609 0.028974%
1218 ........................................ Town of Enfield ...................................................................... 259 194,810 0.043889%
874 .......................................... Town of Farmville ................................................................... 237 178,946 0.040315%
876 .......................................... Town of Fremont .................................................................... 60 45,303 0.010206%
896 .......................................... Town of Hamilton ................................................................... 40 30,202 0.006804%
897 .......................................... Town of Hertford .................................................................... 203 153,274 0.034531%
898 .......................................... Town of Hobgood ................................................................... 46 34,732 0.007825%
877 .......................................... Town of Hookerton ................................................................. 30 22,651 0.005103%
879 .......................................... Town of La Grange ................................................................ 93 70,219 0.015820%
868 .......................................... Town of Louisburg .................................................................. 857 2,552,452 0.575041%
883 .......................................... Town of Pikeville .................................................................... 40 30,202 0.006804%
884 .......................................... Town of Red Springs ............................................................. 117 88,340 0.019902%
1207 ........................................ Town of Richlands .................................................................. 500 377,569 0.085062%
899 .......................................... Town of Robersonville ............................................................ 232 175,170 0.039464%
900 .......................................... Town of Scotland Neck .......................................................... 304 229,533 0.051711%
886 .......................................... Town of Selma ....................................................................... 183 138,173 0.031129%
887 .......................................... Town of Smithfield .................................................................. 378 285,407 0.064299%
901 .......................................... Town of Tarboro ..................................................................... 2,145 1,619,568 0.364872%
888 .......................................... Town of Wake Forest ............................................................. 149 112,501 0.025345%
1217 ........................................ Town of Wakefield .................................................................. 106 79,723 0.017961%
1219 ........................................ Town of Windsor .................................................................... 331 248,946 0.056085%
866 .......................................... Tri-County EMC ...................................................................... 3,096 9,220,782 2.077345%
867 .......................................... Wake EMC ............................................................................. 2,164 6,445,017 1.451994%
Total ................................. ................................................................................................. 196,500 443,873,428 ........................
Energy to be Furnished by the midnight on the last day of each SUMMARY: The Director, Office of Water
Government: calendar month. and Watersheds, EPA Region 10 is
The Government will sell to the [FR Doc. 2015–24196 Filed 9–22–15; 8:45 am] publishing notice of availability of the
Customer and the Customer will BILLING CODE 6450–01–P
final National Pollutant Discharge
Elimination System (NPDES) General
purchase from the Government energy
Permit for Tribal Marine Net Pen
each billing month equivalent to a
Enhancement Facilities in Washington
percentage specified by contract of the ENVIRONMENTAL PROTECTION
State (General Permit). The General
energy made available to the Facilitator AGENCY
Permit authorizes discharges to Waters
(less any losses required by the [FRL–9934–35–Region 10] of the U.S. within the State of
Facilitator). The customer’s contract Washington. The General Permit
demand and accompanying energy will Issuance of NPDES General Permit for contains effluent limitations, along with
be allocated proportionately to its Tribal Marine Net Pen Enhancement administrative reporting and monitoring
mstockstill on DSK4VPTVN1PROD with NOTICES
individual delivery points served from Facilities in Washington State (Permit requirements, as well as standard
the Facilitator’s system. Number WAG132000) conditions, prohibitions, and
Billing Month: AGENCY: Environmental Protection management practices.
Agency (EPA). DATES: The issuance date of the General
The billing month for power sold
Permit is September 23, 2015. The
under this schedule shall end at 12:00 ACTION: Notice of availability of final
effective date of this General Permit will
NPDES General Permit.
be November 1, 2015. Existing operators
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Document Created: 2015-12-15 09:44:37
Document Modified: 2015-12-15 09:44:37
| Category | Regulatory Information | |
| Collection | Federal Register | |
| sudoc Class | AE 2.7: GS 4.107: AE 2.106: | |
| Publisher | Office of the Federal Register, National Archives and Records Administration | |
| Section | Notices | |
| Action | Notice of interim approval. | |
| Dates | The rates are effective October 1, 2015. | |
| Contact | Virgil G. Hobbs III, Assistant Administrator, Finance and Marketing, Southeastern Power Administration, Department of Energy, 1166 Athens Tech Road, Elberton, Georgia 30635-4578, (706) 213-3800. | |
| FR Citation | 80 FR 57353 |
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