82 FR 57742 - Pick-Sloan Missouri Basin Program-Eastern Division-Rate Order No. WAPA-180
DEPARTMENT OF ENERGY
Western Area Power Administration Federal Register Volume 82, Issue 234 (December 7, 2017)
Western Area Power Administration
Federal Register Volume 82, Issue 234 (December 7, 2017)
| Page Range | 57742-57750 | |
| FR Document | 2017-26376 |
[Federal Register Volume 82, Number 234 (Thursday, December 7, 2017)] [Notices] [Pages 57742-57750] From the Federal Register Online [www.thefederalregister.org] [FR Doc No: 2017-26376] ----------------------------------------------------------------------- DEPARTMENT OF ENERGY Western Area Power Administration Pick-Sloan Missouri Basin Program--Eastern Division--Rate Order No. WAPA-180 AGENCY: Western Area Power Administration, DOE. ACTION: Notice of order concerning firm power, firm peaking power, and sale of surplus product formula rates. ----------------------------------------------------------------------- SUMMARY: The Deputy Secretary of Energy confirmed and approved Rate Order No. WAPA-180 and Rate Schedules P-SED-F13, P-SED-FP13, and P-SED- M1 for firm power service, firm peaking power service, and a new formula rate for sale of surplus products for the Western Area Power Administration (WAPA) Pick-Sloan Missouri Basin Program--Eastern Division (P-SMBP--ED) into effect on an interim basis (Provisional Formula Rates). DATES: The Rate Schedules P-SED-F13, P-SED-FP13, and P-SED-M1 are effective on the first day of the first full billing period beginning on or after January 1, 2018, and will remain in effect through December 31, 2022, pending confirmation and approval by Federal Energy Regulatory Commission (FERC) on a final basis or until superseded. FOR FURTHER INFORMATION CONTACT: Mr. Jody S. Sundsted, Acting Regional Manager, Upper Great Plains Region, Western Area Power Administration, 2900 4th Avenue North, Billings, MT 59101-1266, telephone (406) 255- 2800, or Ms. Linda Cady-Hoffman, Rates Manager, Upper Great Plains Region, Western Area Power Administration, 2900 4th Avenue North, Billings, MT 59101-1266, telephone (406) 255-2920, email [email protected]. SUPPLEMENTARY INFORMATION: Firm Electric Service On December 2, 2014, the Deputy Secretary of Energy approved, on an interim basis, Rate Schedules P-SED-F12 and P-SED-FP12 under Rate Order No. WAPA-166 for the 5-year period beginning January 1, 2015, and ending December 31, 2019 (79 FR 72670-72677 (Dec. 8, 2014)).\1\ These rate schedules are formula-based, providing for adjustments to the Drought Adder component.\2\ On January 1, 2017, the Drought Adder component of the P-SMBP--ED effective rate schedule was adjusted downward, recognizing repayment of drought costs included in the Drought Adder component of the approved formula rates. Under Rate Schedule P-SED-F12 with adjusted Drought Adder component as of January 1, 2017, the firm capacity charge is $6.50/kWmonth and the firm energy charge is 16.18 mills/kWh. Under Rate Schedule P-SED-FP12, the firm peaking capacity charge is $5.85/kWmonth. Firm peaking energy is normally returned. A firm peaking energy charge of 16.18 mills/kWh will be assessed in the event energy is not returned. --------------------------------------------------------------------------- \1\ FERC confirmed and approved Rate Order WAPA-166 on a final basis on March 18, 2015, in Docket No. EF15-3-000. See United States Department of Energy, Western Area Power Administration (Pick-Sloan Missouri Basin Program--Eastern Division), 150 FERC ] 62,170. \2\ The Drought Adder component is a formula-based revenue requirement that includes future purchase power above timing purchases, previous purchase power drought deficits, and interest on the purchase power drought deficits. See 72 FR 64067 (November 14, 2007). The Drought Adder was added as a component to the energy and capacity rates in Rate Order No. WAPA-135, which was approved by the Deputy Secretary on an interim basis on November 14, 2007 (72 FR 64067). FERC confirmed and approved Rate Order WAPA-135 on a final basis on April 14, 2008, in Docket No. EF08-5031. See United States Department of Energy, Western Area Power Administration (Pick-Sloan Missouri Basin Program-Eastern Division), 123 FERC ] 62,048. WAPA reviews the Drought Adder component each September to determine if drought costs differ from those projected in the Power Repayment Study and whether an adjustment to the Drought Adder component is necessary. See 72 FR 64071. The Drought Adder component may be adjusted downward using the approved annual Drought Adder adjustment process, whereas an incremental upward adjustment to the Drought Adder component greater than the equivalent of 2 mills/kWh requires a public rate process. See 72 FR 64071. --------------------------------------------------------------------------- Effective January 1, 2018, WAPA is adjusting the overall composite rate of the Pick-Sloan Missouri Basin Program, which is reflected in an adjustment to the formula-based charge components of the firm power rate schedules. The Drought Adder component of the firm power rate schedules will go down to zero and the Base component will be adjusted upward to reflect present costs attributed to the charge components. WAPA's Upper Great Plains Region (UGP) is removing the 5 percent voltage discount in the existing P-SMBP--ED firm power rate schedule P- SED-F12 and removing the voltage discount from the firm power revenue requirement. The total annual revenue requirement for P-SMBP--ED is $230.1 million for firm power service and firm peaking power service. Under Rate Schedule P-SED-F13, the firm capacity charge is $5.25/ kWmonth and the firm energy charge is 13.27 mills/kWh. Under Rate Schedule P-SED-FP13, the firm peaking capacity charge is $4.75/kWmonth. Firm Peaking Energy is normally returned. A [[Page 57743]] Firm Peaking Energy charge of 13.27 mills/kWh will be assessed in the event energy is not returned. Sale of Surplus Products In addition to the firm power and firm peaking power rate schedules, WAPA is implementing a new formula-based rate schedule, P- SED-M1, applicable to the sale of surplus energy and capacity products; energy, reserves, regulation, and frequency response. If P-SMBP--ED surplus products are available, the charge for each product will be determined based on market rates plus administrative costs. The customer will be responsible for acquiring transmission service necessary to deliver the product(s), for which a separate charge may be incurred. Legal Authority By Delegation Order No. 00-037.00B, effective November 19, 2016, the Secretary of Energy delegated: (1) The authority to develop power and transmission rates to the Administrator of WAPA; (2) the authority to confirm, approve, and place such rates into effect on an interim basis to the Deputy Secretary of Energy; and (3) the authority to confirm, approve, and place into effect on a final basis, to remand or to disapprove such rates to FERC. Federal rules (10 CFR part 903) govern DOE procedures for public participation in power rate adjustments. Under Delegation Order Nos. 00-037.00B and 00-001.00F and in compliance with 10 CFR part 903 and 18 CFR part 300, I hereby confirm, approve, and place Rate Order No. WAPA-180, which provides the formula rates for P-SMBP--ED firm power, firm peaking power, and sale of surplus products, into effect on an interim basis. The new Rate Schedules P-SED-F13, P-SED-FP13, and P-SED-M1 will be submitted to FERC for confirmation and approval on a final basis. Dated: November 30, 2017. Dan Brouillette, Deputy Secretary of Energy. DEPARTMENT OF ENERGY DEPUTY SECRETARY In the matter of: Western Area Power Administration Rate Adjustment for the Pick-Sloan Missouri Basin Program--Eastern Division) Rate Order No. WAPA-180 ORDER CONFIRMING, APPROVING, AND PLACING THE PICK-SLOAN MISSOURI BASIN PROGRAM--EASTERN DIVISION FIRM POWER SERVICE, FIRM PEAKING POWER SERVICE AND SALE OF SURPLUS PRODUCT FORMULA RATES INTO EFFECT ON AN INTERIM BASIS The firm power, firm peaking power, and sale of surplus product rates for the Pick-Sloan Missouri Basin Program--Eastern Division (P- SMBP--ED) set forth in this order are established in accordance with section 302 of the Department of Energy (DOE) Organization Act (42 U.S.C. 7152). This Act transferred to and vested in the Secretary of Energy the power marketing functions of the Secretary of the Department of the Interior and the Bureau of Reclamation (Reclamation) under the Reclamation Act of 1902 (ch. 1093, 32 Stat. 388), as amended and supplemented by subsequent laws, particularly section 9(c) of the Reclamation Act of 1939 (43 U.S.C. 485h(c)) and section 5 of the Flood Control Act of 1944 (16 U.S.C. 825s), and other acts that specifically apply to the projects involved. By Delegation Order No. 00-037.00B, effective November 19, 2016, the Secretary of Energy delegated: (1) the authority to develop power and transmission rates to the Administrator of Western Area Power Administration (WAPA); (2) the authority to confirm, approve, and place such rates into effect on an interim basis to the Deputy Secretary of Energy; and (3) the authority to confirm, approve, and place into effect on a final basis, to remand, or to disapprove such rates to the Federal Energy Regulatory Commission (FERC). Federal rules (10 CFR part 903) govern DOE procedures for public participation in power rate adjustments. Acronyms, Terms and Definitions As used in this Rate Order, the following acronyms, terms and definitions apply: Base: A fixed revenue requirement that includes O&M expense, investments and replacements, interest on investments and replacements, normal timing power purchase (purchases due to operational constraints, not associated with drought), and transmission costs. Capacity: The electric capability of a generator, transformer, transmission circuit, or other equipment. It is expressed in kilowatts. Capacity Rate: The rate which sets forth the charges for capacity. It is expressed in dollars per kilowatt-month and applied to each kilowatt of the Contract Rate of Delivery (CROD). Composite Rate: The Power Repayment Study (PRS) rate for commercial firm power, which is the total annual revenue requirement for capacity and energy divided by the total annual energy sales. It is expressed in mills per kilowatt-hour and used only for comparison purposes. Customer: An entity with a contract that is receiving firm electric service from WAPA. Deficits: Deferred or unrecovered annual and/or interest expenses. DOE Order RA 6120.2: An order outlining power marketing administration financial reporting and rate-making procedures. Drought Adder: A formula-based revenue requirement that includes future purchase power above timing purchases, previous purchase power drought deficits, and interest on the purchase power drought deficits. Energy: Measured in terms of the work it is capable of doing over a period of time. Electric energy is expressed in kilowatt-hours. Energy Charge: The charge under the rate schedule for energy. It is expressed in mills per kilowatt-hour and applied to each kilowatt-hour delivered to each Customer. Firm: A type of product and/or service available at the time requested by a Customer. FY: Fiscal year; October 1 to September 30. kW: Kilowatt--the electrical unit of capacity that equals 1,000 watts. kWh: Kilowatt-hour--the electrical unit of energy that equals 1,000 watts in 1 hour. kWmonth: Kilowatt-month the electrical unit of the monthly amount of capacity. LAP Loveland Area Projects mills/kWh: Mills per kilowatt-hour--the unit of charge for energy (equal to one tenth of a cent or one thousandth of a dollar). MW: Megawatt--the electrical unit of capacity that equals 1 million watts or 1,000 kilowatts. Non-timing Power Purchases: Power purchases that are not related to operational constraints such as management of endangered species, species habitat, water quality, navigation, control area purposes, etc. O&M Operation and Maintenance. P-SMBP: The Pick-Sloan Missouri Basin Program. P-SMBP--ED: Pick-Sloan Missouri Basin Program--Eastern Division. P-SMBP--WD: Pick-Sloan Missouri Basin Program--Western Division. Power: Capacity and energy. Power Factor: The ratio of real to apparent power at any given point and [[Page 57744]] time in an electrical circuit. Generally, it is expressed as a percentage. Preference: The provisions of Reclamation Law that require WAPA to first make Federal power available to certain entities. For example, section 9(c) of the Reclamation Project Act of 1939 (43 U.S.C. 485h(c)) states that preference in the sale of Federal power shall be given to municipalities and other public corporations or agencies and also to cooperatives and other nonprofit organizations financed in whole or in part by loans made under the Rural Electrification Act of 1936. Provisional Formula Rate: A formula rate confirmed, approved, and placed into effect on an interim basis by the Deputy Secretary of Energy. Ratesetting PRS: The Power Repayment Study used for the rate adjustment period. Revenue Requirement: The revenue required by PRS to recover annual expenses (such as O&M, purchase power, transmission service expenses, interest, and deferred expenses) and repay Federal investments and other assigned costs. Effective Date The Provisional Formula Rate Schedules P-SED-F13, P-SED-FP13, and P-SED-M1 will take effect on the first day of the first full billing period beginning on or after January 1, 2018, and will remain in effect through December 31, 2022, pending approval by FERC on a final basis or until superseded. Public Notice and Comment WAPA-UGP followed the Procedures for Public Participation in Power and Transmission Rate Adjustments and Extensions, 10 CFR part 903, in developing these rates and schedules. The steps WAPA took to involve interested parties in the rate process were: 1. A Federal Register Notice, published on July 3, 2017 (82 FR 30858) (Proposal FRN), announced the proposed rates for P-SMBP--ED and began the 90-day public consultation and comment period. 2. On July 5, 2017, WAPA-UGP mailed letters to all P-SMBP--ED Preference Customers and interested parties transmitting the FRN published on July 3, 2017. 3. On August 22, 2017, at 9 a.m. (MDT), WAPA held a public information forum at the Denver Embassy Suites, 7000 Yampa Street, Denver, Colorado. WAPA provided updates to the proposed firm power rates and sale of surplus products for both P-SMBP--ED and Loveland Area Projects (LAP). WAPA also answered questions and gave notice that more information was available in the customer rate brochure. 4. On August 22, 2017, at 11 a.m. (MDT), following the public information forum, at the same location, a public comment forum was held, to provide an opportunity for customers and other interested parties to comment for the record. No oral or written comments were received at this forum. 5. On August 23, 2017, at 9 a.m. (CDT), WAPA held a public information forum at the Holiday Inn, 100 West 8th Street, Sioux Falls, South Dakota. WAPA provided updates to the proposed firm power rates and sale of surplus products for both the P-SMBP--ED and LAP. WAPA also answered questions and gave notice that more information was available in the customer rate brochure. 6. On August 23, 2017, at 11 a.m. (CDT), following the public information forum, and at the same location, a public comment forum was held. The comment forum gave the public an opportunity to comment for the record. Two oral comments were received at this forum. 7. WAPA provided a Web site that contains all dates, customer letters, presentations, FRNs, customer rate brochure, and other information about this rate process. The Web site is located at https://www.wapa.gov/regions/UGP/rates/Pages/2018-firm-rate-adjustment.aspx. 8. During the 90-day consultation and comment period, which ended October 2, 2017, WAPA received two oral comments (at the August 23 public comment forum) and two comment letters. The comments and WAPA's responses are addressed below. All comments have been considered in the preparation of this Rate Order. Two representatives of the following organizations made oral comments Mid-West Electric Consumers Association, Colorado Missouri River Energy Services, South Dakota Written comments were received from the following interested parties Marshall Municipal Utilities, Minnesota Missouri River Energy Services, South Dakota Project Description The Pick-Sloan Missouri Basin Program (P-SMBP), originally the Missouri River Basin Project, was authorized by Congress in section 9 of the Flood Control Act of 1944 of December 22, 1944 (Pub. L. 534, 58 Stat. 887, 891). This multipurpose program provides flood control, irrigation, navigation, recreation, preservation and enhancement of fish and wildlife, and power generation. Multipurpose projects have been developed on the Missouri River and its tributaries in Colorado, Montana, Nebraska, North Dakota, South Dakota, and Wyoming. In addition to the multipurpose water projects authorized by section 9 of the Flood Control Act of 1944, certain other existing projects have been integrated with the P-SMBP for power marketing, operation, and repayment purposes. The Colorado-Big Thompson, Kendrick, Riverton, and Shoshone Projects were combined with the P-SMBP in 1954, followed by the North Platte Project in 1959. These projects were referred to as the ``Integrated Projects'' of the P-SMBP. The Flood Control Act of 1944 also authorized the inclusion of the Fort Peck Project with the P-SMBP for operation and repayment purposes. The Riverton Project was reauthorized as a unit of P-SMBP in 1970. The P-SMBP power is marketed by two Regions. The UGP Region, with a regional office in Billings, Montana, markets the Eastern Division (P- SMBP--ED) power to approximately 340 customers. The Rocky Mountain Region (RMR), with a regional office in Loveland, Colorado, markets the Western Division (P-SMBP--WD) power through LAP to approximately 75 customers. The adjustment to the LAP rate is a separate formal rate process, which is documented in Rate Order No. WAPA-179. Rate Order No. WAPA-179 is also scheduled to go into effect on the first day of the first full billing period on or after January 1, 2018. The P-SMBP--WD revenue requirement is incorporated into the LAP rate, along with the revenue requirement for the Fryingpan-Arkansas Project. Power Repayment Study--Firm Power Rate WAPA prepares a PRS each FY to determine if revenues will be sufficient to repay, within the required time, all costs assigned to the P-SMBP. Repayment criteria is based on WAPA's applicable laws and legislation, as well as policies including DOE Order RA 6120.2. To meet the Cost Recovery Criteria outlined in DOE Order RA 6120.2, a revised study and rate adjustment has been developed to demonstrate that sufficient revenues will be collected under Provisional Formula Rates to meet future obligations. [[Page 57745]] With the removal of the voltage discount taken into account, the total annual revenue requirement for P-SMBP--ED is $230.1 million for firm power service and firm peaking power service. The revenue requirement and composite rates for P-SMBP--ED firm power and firm peaking power are being reduced, as indicated in Table 1: Table 1--Comparison of Revenue Requirements and Composite Rates ---------------------------------------------------------------------------------------------------------------- Existing Provisional requirements requirements (January 1, (January 1, Percent change 2017) 2018) ---------------------------------------------------------------------------------------------------------------- P-SMBP--ED Revenue Requirement (millions $)..................... $282.7 $230.1 \1\ -19% P-SMBP--ED Composite Rate (mills/kWh)........................... 28.25 24.00 -15 ---------------------------------------------------------------------------------------------------------------- \1\ Voltage discount removed. Under the existing rate methodology, rates for P-SMBP--ED firm power service and firm peaking power service are designed to recover an annual revenue requirement that includes power investment repayment, aid to irrigation repayment, interest expense, purchase power, O&M, and other expenses within the allowable period. The annual revenue requirement continues to be allocated equally between capacity and energy. Existing and Provisional Formula Rates The existing Rate Schedules P-SED-P12 and P-SED-FP12 and provisional Rate Schedules P-SED-P13 and P-SED-FP13 continue to be formula-based, with Base and Drought Adder components, and provide for an incremental upward adjustment to the Drought Adder component up to 2 mills/kwh. An incremental increase to the Drought Adder greater than 2 mills/kWh requires a public process. The Drought Adder may be adjusted downward pursuant to the formula, by using the approved annual Drought Adder adjustment process. A comparison of the existing and Provisional Formula Rates for P-SMBP--ED firm electric service is listed in Table 2: Table 2--Comparison of Existing and Provisional Formula Rates ---------------------------------------------------------------------------------------------------------------- Existing charges under Provisional P-SED-F12/ P- charges under SED-FP12 with P-SED-F13/ P- Firm power service modified SED-FP13 as of Percent change drought adder January 1, as of January 2018 1, 2017 ---------------------------------------------------------------------------------------------------------------- Firm Capacity ($/kW month)...................................... $6.50 $5.25 -19 Firm Energy (mills/kWh)......................................... 16.18 13.27 -18 Firm Peaking Capacity ($/kW month).............................. $5.85 $4.75 -19 Firm Peaking Energy (mills/kWh) \1\............................. 16.18 13.27 -18 ---------------------------------------------------------------------------------------------------------------- \1\ Firm Peaking Energy is normally returned. This charge will be assessed in the event Firm Peaking Energy is not returned. Under the new formula-based Rate Schedule P-SED-M1, the Provisional Formula Rate will consist of a charge for products listed in the rate schedule that will be determined at the time of the sale based on market rates, plus administrative costs. Certification of Rates WAPA's Administrator certified that the Provisional Formula Rates for P-SMBP--ED firm power, firm peaking power, and sale of surplus product rates under Rate Schedules P-SED-F13, P-SED-FP13, and P-SED-M1 are at the lowest possible rates consistent with sound business principles. The Provisional Formula Rates were developed following administrative policies and applicable laws. P-SMBP--ED Firm Power Rate Discussion According to Reclamation Law, WAPA is required to establish power rates sufficient to recover O&M, purchased power and interest expenses, and repay power investment and irrigation aid. The P-SMBP--ED firm power and firm peaking power Base and Drought Adder components are updated to represent present costs. As a part of the existing and provisional rate schedules, WAPA provides for a formula-based adjustment of the Drought Adder component of up to 2 mills/kWh. The 2 mills/kWh cap places a limit on the amount the Drought Adder component can be adjusted relative to associated drought costs to recover costs attributable to the Drought Adder formula rate for any one-year cycle. Continuing to identify the firm power service revenue requirement using Base and Drought Adder components will assist WAPA in the presentation of future impacts of droughts, demonstrate repayment of drought-related costs in the PRS, and allow WAPA to be more responsive to changes caused by drought-related expenses. WAPA will continue to charge and bill its Preference Customers firm power service and firm peaking power service rates for energy and capacity, which are the sum of the Base and Drought Adder components. Under Rate Schedules P-SED-F13 and P-SED-FP13, WAPA will continue to identify its firm power revenue requirement using Base and Drought Adder components. The Base component is a fixed revenue requirement that includes annual O&M expenses, investment repayment and associated interest, normal timing power purchases, and transmission costs. Normal timing power purchases [[Page 57746]] are due to operational constraints (e.g., management of endangered species habitat, water quality, navigation, etc.) and are not associated with drought. WAPA cannot adjust the Base component without a public process. The Drought Adder component is a formula-based revenue requirement that includes costs attributable to drought conditions within P-SMBP. The Drought Adder component includes costs associated with future Non- timing Power Purchases to meet firm power contractual obligations not covered with available system generation due to a drought, previously incurred deficits due to purchased power debt that resulted from Non- timing Power Purchases made during a drought, and the interest associated with drought debt. The Drought Adder component is designed to repay WAPA's drought debt within 10 years from the time the debt was incurred, using balloon-payment methodology. For example, the drought debt incurred by WAPA in FY 2009 is required to be repaid by FY 2019. The annual revenue requirement calculation will continue to be summarized by the following formula: Annual Revenue Requirement = Base Revenue Requirement + Drought Adder Revenue Requirement. Both the Base and Drought Adder components recover portions of the firm power revenue requirement and firm peaking power revenue necessary to equal the P- SMBP--ED revenue requirement. Under this Provisional Rate, the P-SMBP-- ED annual revenue requirement equals $230.1 million and is comprised of a Base revenue requirement of $230.1 million plus a Drought Adder revenue requirement of $0. A comparison of the existing and provisional charge components is listed in Table 3. Table 3--Summary of P-SMBP--ED Charge Components -------------------------------------------------------------------------------------------------------------------------------------------------------- Existing charges under rate schedules P-SED- Provisional charges under rate schedules P-SED- Change F12 and P-SED-FP12 with modified drought F13 and P-SED-FP13 as of January 1, 2018 --------------- adder as of January 1, 2017 ------------------------------------------------ ------------------------------------------------ Base Drought Adder Base Drought Adder Total charge (%) component component Total charge component component -------------------------------------------------------------------------------------------------------------------------------------------------------- Firm Capacity $4.90 $1.60 $6.50 $5.25 $0.00 $5.25 -19% (/kWmonth)............................. Firm Energy (mills/kWh)................. 12.33 3.85 16.18 13.27 0.00 13.27 -18% Firm Peaking Capacity ($/kWmonth)....... $4.45 $1.40 $5.85 $4.75 $0.00 $4.75 -19% Firm Peaking Energy (mills/kWh) \1\..... 12.33 3.85 16.18 13.27 0.00 13.27 -18% -------------------------------------------------------------------------------------------------------------------------------------------------------- \1\ Firm Peaking Energy is normally returned. This charge will be assessed in the event Firm Peaking Energy is not returned. WAPA reviews its firm power service rates annually. WAPA will review the Base and Drought Adder components after the annual PRS is completed, generally in the first quarter of the calendar year. If an adjustment to the Base component is necessary or if an incremental upward adjustment to the Drought Adder component greater than the equivalent of 2 mills/kWh to the PRS Composite Rate is necessary, WAPA will initiate a public process following 10 CFR part 903 before making an adjustment. In accordance with the approved Drought Adder adjustment process, WAPA will review the Drought Adder component annually in early summer to determine if drought costs differ from those projected in the PRS. In October, WAPA will determine if a change to the Drought Adder component is necessary, either incremental or decremental. Adjustment to the Drought Adder component, up to 2 mills/kWh, will be implemented in the following January billing cycle. Although decremental adjustments to the Drought Adder component will occur as drought costs are repaid, the adjustments cannot result in a negative Drought Adder component. Implementing the Drought Adder component adjustment on January 1 of each year will help keep the drought deficits from escalating as quickly, will lower the interest expense due to drought deficits, will demonstrate responsible deficit management, and will provide prompt drought deficit repayments. Statement of Revenue and Related Expenses The following Table 4 provides a summary of projected revenue and expense data for the P-SMBP, including both the Eastern and Western Division's firm electric service revenue requirements, through the 5- year provisional rate approval period. The firm power rates for Eastern and Western Divisions have been developed with the following revenues and expenses for the P-SMBP: Table 4--P-SMBP Comparison of 5-Year Rate Period (FY 2018-2022) Total Revenues and Expenses ---------------------------------------------------------------------------------------------------------------- Existing Rate Provisional Rate ($000) ($000) Difference ($000) ---------------------------------------------------------------------------------------------------------------- Total Revenues\1\...................................... $2,679,973 $2,644,825 ($35,148) ---------------------------------------------------------------------------------------------------------------- Revenue Distribution Expenses: O&M.................................................... $1,082,969 $1,158,866 $75,897 Purchased Power........................................ 164,049 124,796 (39,253) Interest............................................... 561,528 560,257 (1,271) Transmission\1\........................................ 64,072 460,982 396,910 ---------------------------------------------------------------------------------------------------------------- Total Expenses..................................... $1,872,618 $2,304,901 $432,283 [[Page 57747]] Principal Payments: Capitalized Expenses (Deficits) \2\.................... $345,006 $42,325 ($302,681) Original Project and Additions \2\..................... 401,193 179,017 (222,176) Replacements \2\....................................... 61,156 72,864 11,708 Irrigation Aid......................................... 0 45,718 45,718 -------------------------------------------------------- Total Principal Payments........................... $807,355 $339,924 ($467,431) -------------------------------------------------------- Total Revenue Distribution......................... $2,679,973 $2,644,825 ($35,148) ---------------------------------------------------------------------------------------------------------------- \1\ Transmission increase is a result of accounting treatment of transmission expense and transmission revenue due to WAPA-UPG joining the Southwest Power Pool (SPP). \2\ Due to historic drought conditions, revenues generated in the cost evaluation period are applied toward repayment of deferred annual expenses rather than repayment of project additions and replacements. The outstanding deferred of amount $42.3 million is projected to be repaid in 2018, a year ahead of its due date. Sale of Surplus Products Discussion WAPA is also implementing a new formula rate for the sale of surplus products under Rate Schedule P-SED-M1. This new rate schedule allows for the sale of generation and generation-related products in excess of WAPA's P-SMBP--ED firm power obligations at market rates. P- SED-M1 is a new formula-based rate schedule, applicable to the sale of surplus energy and capacity products. The schedule includes reserves, regulation, frequency response, and energy. If WAPA UGP surplus products are available, the charge is determined based on market rates, plus administrative costs. The customer will be responsible for acquiring transmission service necessary to deliver the product(s) for which a separate charge may be incurred. WAPA is placing Rate Schedule P-SED-M1 into effect for the 5-year period beginning January 1, 2018, through December 31, 2022. Basis for Rate Development WAPA is lowering the overall charges for firm power service and firm peaking power service by 19 percent, by reducing the Drought Adder component to zero, increasing the Base component, and removing the voltage discount. The Provisional Formula Rates under Rate Schedules P- SED-F13 and P-SED-FP13 will provide sufficient revenue to pay all annual costs, including interest expense, and repay investments within the allowable periods. Comments WAPA received two comment letters and two oral comments during the public consultation and comment period. The comments expressed in these letters have been paraphrased, where appropriate, without compromising the meaning of the comments. A. Comment: One customer expressed support of the proposed rate adjustment as described in the FRN for Rate Order No. WAPA-180. The customer is aware that WAPA intends to lower the Drought Adder to zero and increase the Base component due to inflationary pressures. The customer also expressed support of removing the voltage discount. The customer commended WAPA on paying off the $843 million in drought debt as a significant achievement. The customer acknowledged much has been learned about the risks of power supply management through drought periods. The customer encouraged WAPA to work towards implementing a purchase power and wheeling strategy for WAPA's unobligated balances to help manage such risks in the future. Response: This rate reduction rebalances the Base and Drought Adder components. WAPA has also determined that the voltage discount has served its purpose and now is no longer needed. In its nearly 70 years of application, the original intent of reimbursing customers for relieving the BOR and then WAPA of transmission facility construction costs has been met. The purchase power and wheeling strategy, as well as the use of unobligated balances, are not directly related to this rate action. WAPA will, however, continue to complete an annual Drought Adder review that allows WAPA to be more responsive to rate adjustments driven by drought periods. WAPA is committed to continuing to implement its purchase power and wheeling strategy and use of unobligated balances in an open and transparent manner. B. Comment: Multiple customer representatives supported the rate adjustment as proposed, and emphasized the need for continued cost control regarding the Base component. Response: WAPA is committed to keeping the power rates at the lowest possible rates while maintaining sound business principles. Availability of Information Information about this rate adjustment, including the customer rate brochure, PRS, comments, letters, memorandums, and other supporting materials that were used to develop the Provisional Formula Rates, is be available for inspection and copying at the Upper Great Plains Regional Office, located at 2900 4th Avenue North, 6th Floor, Billings, Montana. Many of these documents are also available on WAPA's Web site under the ``2018 Firm Rate Adjustment'' section located at https://www.wapa.gov/regions/UGP/rates/Pages/2018-firm-rate-adjustment.aspx. RATEMAKING PROCEDURE REQUIREMENTS Environmental Compliance In compliance with the National Environmental Policy Act (NEPA) of 1969, 42 U.S.C. 4321-4347: the Council on Environmental Quality Regulations for implementing NEPA (40 CFR parts 1500-1508): and DOE NEPA Implementing Procedures and Guidelines (10 CFR part 1021), WAPA has determined this action is categorically excluded from preparing an environmental assessment or an environmental impact statement. A copy of the categorical exclusion determination is available on WAPA's Web site at http://www.wapa.gov/regions/UGP/Environment/Documents/RateOrderWAPA-180.pdf. [[Page 57748]] Determination Under Executive Order 12866 WAPA has an exemption from centralized regulatory review under Executive Order 12866; accordingly, no clearance of this notice by the Office of Management and Budget is required. Submission to the Federal Energy Regulatory Commission The Provisional Formula Rates herein confirmed, approved, and placed into effect on an interim basis, together with supporting documents, will be submitted to FERC for confirmation and final approval. ORDER In view of the foregoing and under the authority delegated to me, I confirm and approve on an interim basis, effective on the first full billing period on or after January 1, 2018, Rate Schedules P-SED-F13, P-SED-FP13, and P-SED-M1 for the Pick-Sloan Missouri Basin Program-- Eastern Division Project of the Western Area Power Administration. These rate schedules shall remain in effect on an interim basis, pending Federal Energy Regulatory Commission's confirmation and approval of the rate schedules or substitute rates on a final basis through December 31, 2022, or until superseded. Dated: November 30, 2017 Dan Brouillette Deputy Secretary of Energy Rate Schedule P-SED-F13 (Supersedes Schedule P-SED-F12) UNITED STATES DEPARTMENT OF ENERGY WESTERN AREA POWER ADMINISTRATION UPPER GREAT PLAINS REGION Pick-Sloan Missouri Basin Program--Eastern Division FIRM POWER SERVICE (Approved Under Rate Order No. WAPA-180) Effective The first day of the first full billing period beginning on or after January 1, 2018, through December 31, 2022, or until superseded by another rate schedule, whichever occurs earlier. Available Within the marketing area served by the Eastern Division of the Pick-Sloan Missouri Basin Program; within Montana, North Dakota, South Dakota, Minnesota, Iowa, and Nebraska. Applicable To the power and energy delivered to customers as firm power service. Character Alternating current, 60 hertz, three phase, delivered and metered at the voltages and points established by contract. Formula Rate and Charge Components Rate = Base component + Drought Adder component. Monthly Charge as of January 1, 2018, under the Rate: CAPACITY CHARGE: $5.25 for each kilowatt per month (kWmo) of billing capacity. ENERGY CHARGE: 13.27 mills for each kilowatt-hour (kWh) for all energy delivered as firm power service. BILLING CAPACITY: The billing capacity will be as defined by the power sales contract. Charge Components Base Component: A fixed revenue requirement that includes operation and maintenance expense, investments and replacements, interest on investments and replacements, normal timing purchase power (purchases due to operational constraints, not associated with drought), and transmission costs. Any proposed change to the Base component will require a public process. [GRAPHIC] [TIFF OMITTED] TN07DE17.001 Drought Adder Component: A formula-based revenue requirement that includes future purchase power expense above timing purchases, previous purchase power drought deficits, and interest on the purchase power drought deficits. The formulas, along with the charges under the formulas as of January 1, 2018, are: [GRAPHIC] [TIFF OMITTED] TN07DE17.002 Annual Drought Adder Adjustment Process: The Drought Adder may be adjusted annually using the above formulas for any costs attributed to drought of less than or equal to the equivalent of 2 mills/kWh to the Power Repayment Study (PRS) composite rate. Any planned incremental upward adjustment to the Drought Adder greater than the equivalent of 2 mills/kWh to the PRS composite rate will require a public process. The annual review process is initiated in early summer when WAPA reviews the Drought Adder component and provides notice of any estimated change to the Drought Adder component charge under the formula. In October, WAPA will make a final determination of any change to the Drought Adder component charge, either incremental or decremental. If a Drought Adder component change is required, a modified Drought Adder revenue requirement and the associated charges will become effective the following January 1 and will be identified in a Drought Adder modification update. WAPA will inform customers of updates [[Page 57749]] by letter and post updates to WAPA's external Web site. Adjustments: For Billing of Unauthorized Overruns: For each billing period in which there is a contract violation involving an unauthorized overrun of the contractual firm power and/or energy obligations, such overrun shall be billed at 10 times the formula rate. For Power Factor: None. Customers will be required to maintain a power factor at the point of delivery between 95-percent lagging and 95-percent leading. Rate Schedule P-SED-FP13 (Supersedes Schedule P-SED-FP12) UNITED STATES DEPARTMENT OF ENERGY WESTERN AREA POWER ADMINISTRATION UPPER GREAT PLAINS REGION Pick-Sloan Missouri Basin Program--Eastern Division FIRM PEAKING POWER SERVICE (Approved Under Rate Order No. WAPA-180) Effective: The first day of the first full billing period beginning on or after January 1, 2018, through December 31, 2022, or until superseded by another rate schedule, whichever occurs earlier. Available: Within the marketing area served by the Eastern Division of the Pick-Sloan Missouri Basin Program; within Montana, North Dakota, South Dakota, Minnesota, Iowa, and Nebraska. Applicable: To the power sold to customers as firm peaking power service. Character: Alternating current, 60 hertz, three phase, delivered and metered at the voltages and points established by contract. Formula Rate and Charge Components: Rate = Base component + Drought Adder component Monthly Charge as of January 1, 2018, under the Rate: CAPACITY CHARGE: $4.75 for each kilowatt per month (kWmo) of the effective contract rate of delivery for peaking power or the maximum amount scheduled, whichever is greater. ENERGY CHARGE: 13.27 mills for each kilowatt-hour (kWh) for all energy scheduled for delivery without return. Charge Components: Base Component: A fixed revenue requirement that includes operation and maintenance expense, investments and replacements, interest on investments and replacements, normal timing purchase power (purchases due to operational constraints, not associated with drought), and transmission costs. Any proposed change to the Base component will require a public process. [GRAPHIC] [TIFF OMITTED] TN07DE17.005 Drought Adder Component: A formula-based revenue requirement that includes future purchase power above timing purchases, previous purchase power drought deficits, and interest on the purchase power drought deficits. The formulas, along with the charges under the formulas as of January 1, 2018, are: [GRAPHIC] [TIFF OMITTED] TN07DE17.006 Annual Drought Adder Adjustment Process: The Drought Adder may be adjusted annually using the above formulas for any costs attributed to drought of less than or equal to the equivalent of 2 mills/kWh to the Power Repayment Study (PRS) composite rate. Any planned incremental upward adjustment to the Drought Adder greater than the equivalent of 2 mills/kWh to the PRS composite rate will require a public process. The annual review process is initiated in early summer when WAPA reviews the Drought Adder component and provides notice of any estimated change to the Drought Adder component charge under the formula. In October, WAPA will make a final determination of any change to the Drought Adder component charge, either incremental or decremental. If a Drought Adder component change is required, a modified Drought Adder revenue requirement and the associated charges will become effective the following January 1 and will be identified in a Drought Adder modification update. WAPA will inform customers of updates by letter and post updates to WAPA's external Web site. BILLING CAPACITY: The billing capacity will be the greater of (1) the highest 30- minute integrated capacity measured during the month up to, but not in excess of, the delivery obligation under the power sales contract, or (2) the contract rate of delivery. Adjustments: Billing for Unauthorized Overruns: For each billing period in which there is a contract violation involving an unauthorized overrun of the contractual obligation for peaking capacity and/or energy, such overrun shall be billed at 10 times the above rate. Rate Schedule P-SED-M1 [[Page 57750]] UNITED STATES DEPARTMENT OF ENERGY WESTERN AREA POWER ADMINISTRATION UPPER GREAT PLAINS REGION PICK-SLOAN MISSOURI BASIN PROGRAM--EASTERN DIVISION SALE OF SURPLUS PRODUCTS (Approved Under Rate Order No. WAPA-180) Effective: The first day of the first full billing period beginning on or after January 1, 2018, through December 31, 2022, or until superseded by another rate schedule, whichever occurs earlier. Applicable: This rate schedule applies to Eastern Division of the Pick-Sloan Missouri Basin Program marketing and is applicable to the sale of the following P-SMBP--ED surplus energy and capacity products; energy, frequency response, regulation, and reserves. If any P-SMBP--ED surplus energy and capacity products are available, UGP can make the product(s) available for sale, providing entities enter into a separate agreement(s) with UGP Marketing Office which will specify the terms of sale(s). Formula Rate: The charge for each product is determined at the time of the sale based on market rates, plus administrative costs. The customer will be responsible for acquiring transmission services necessary to deliver the product(s), for which a separate charge may be incurred. [FR Doc. 2017-26376 Filed 12-6-17; 8:45 am] BILLING CODE 6450-01-P
![57742 Federal Register / Vol. 82, No. 234 / Thursday, December 7, 2017 / Notices
Adjustments DEPARTMENT OF ENERGY component.2 On January 1, 2017, the
Drought Adder component of the P–
For Transformer Losses: If delivery is Western Area Power Administration SMBP—ED effective rate schedule was
made at transmission voltage but adjusted downward, recognizing
metered on the low-voltage side of the Pick-Sloan Missouri Basin Program— repayment of drought costs included in
substation, the meter readings will be Eastern Division—Rate Order No. the Drought Adder component of the
increased to compensate for transformer WAPA–180 approved formula rates. Under Rate
losses as provided for in the contract. Schedule P–SED–F12 with adjusted
AGENCY:Western Area Power
For Power Factor: None. The customer Drought Adder component as of January
Administration, DOE. 1, 2017, the firm capacity charge is
will be required to maintain a power
ACTION: Notice of order concerning firm $6.50/kWmonth and the firm energy
factor at all points of measurement
power, firm peaking power, and sale of charge is 16.18 mills/kWh. Under Rate
between 95-percent lagging and
surplus product formula rates. Schedule
95-percent leading.
P-SED-FP12, the firm peaking capacity
SUMMARY: The Deputy Secretary of charge is $5.85/kWmonth. Firm peaking
Rate Schedule L–M2 Energy confirmed and approved Rate energy is normally returned. A firm
(Supersedes Rate Schedule L–M1) Order No. WAPA–180 and Rate peaking energy charge of 16.18 mills/
Schedules P-SED-F13, P-SED-FP13, and kWh will be assessed in the event
UNITED STATES DEPARTMENT OF
P–SED–M1 for firm power service, firm energy is not returned.
ENERGY
peaking power service, and a new Effective January 1, 2018, WAPA is
WESTERN AREA POWER formula rate for sale of surplus products adjusting the overall composite rate of
ADMINISTRATION for the Western Area Power the Pick-Sloan Missouri Basin Program,
Administration (WAPA) Pick-Sloan which is reflected in an adjustment to
ROCKY MOUNTAIN REGION the formula-based charge components of
Missouri Basin Program—Eastern
Loveland Area Projects Division (P-SMBP—ED) into effect on an the firm power rate schedules. The
interim basis (Provisional Formula Drought Adder component of the firm
SALE OF SURPLUS PRODUCTS power rate schedules will go down to
Rates).
(Approved Under Rate Order No. zero and the Base component will be
DATES: The Rate Schedules P-SED-F13, adjusted upward to reflect present costs
WAPA–179)
P-SED-FP13, and P-SED-M1 are effective attributed to the charge components.
Effective on the first day of the first full billing WAPA’s Upper Great Plains Region
period beginning on or after January 1, (UGP) is removing the 5 percent voltage
The first day of the first full billing 2018, and will remain in effect through discount in the existing P-SMBP—ED
period beginning on or after January 1, December 31, 2022, pending firm power rate schedule P-SED-F12
2018, and extending through December confirmation and approval by Federal and removing the voltage discount from
31, 2022, or until superseded by another Energy Regulatory Commission (FERC) the firm power revenue requirement.
rate schedule, whichever occurs earlier. on a final basis or until superseded. The total annual revenue requirement
Applicable FOR FURTHER INFORMATION CONTACT: Mr. for P-SMBP—ED is $230.1 million for
Jody S. Sundsted, Acting Regional firm power service and firm peaking
This rate schedule applies to Manager, Upper Great Plains Region, power service. Under Rate Schedule P-
Loveland Area Projects (LAP) Marketing Western Area Power Administration, SED-F13, the firm capacity charge is
and is applicable to the sale of the 2900 4th Avenue North, Billings, MT $5.25/kWmonth and the firm energy
following LAP surplus energy and 59101–1266, telephone (406) 255–2800, charge is 13.27 mills/kWh. Under Rate
capacity products: energy, frequency or Ms. Linda Cady-Hoffman, Rates Schedule P-SED-FP13, the firm peaking
response, regulation, and reserves. If Manager, Upper Great Plains Region, capacity charge is $4.75/kWmonth. Firm
any of the above LAP surplus products Western Area Power Administration, Peaking Energy is normally returned. A
are available, LAP can make the 2900 4th Avenue North, Billings, MT
2 The Drought Adder component is a formula-
product(s) available for sale, providing 59101–1266, telephone (406) 255–2920,
based revenue requirement that includes future
entities enter into separate agreement(s) email cady@wapa.gov. purchase power above timing purchases, previous
with LAP Marketing which will specify SUPPLEMENTARY INFORMATION: purchase power drought deficits, and interest on
the purchase power drought deficits. See 72 FR
the terms of sale(s).
Firm Electric Service 64067 (November 14, 2007). The Drought Adder
was added as a component to the energy and
Formula Rate
On December 2, 2014, the Deputy capacity rates in Rate Order No. WAPA–135, which
Secretary of Energy approved, on an was approved by the Deputy Secretary on an
The charge for each product will be interim basis on November 14, 2007 (72 FR 64067).
determined at the time of the sale based interim basis, Rate Schedules P-SED- FERC confirmed and approved Rate Order WAPA–
on market rates, plus administrative F12 and P-SED-FP12 under Rate Order 135 on a final basis on April 14, 2008, in Docket
costs. The customer will be responsible No. WAPA–166 for the 5-year period No. EF08–5031. See United States Department of
beginning January 1, 2015, and ending Energy, Western Area Power Administration (Pick-
for acquiring transmission service Sloan Missouri Basin Program-Eastern Division),
December 31, 2019 (79 FR 72670–72677 123 FERC ¶ 62,048. WAPA reviews the Drought
necessary to deliver the product(s), for
(Dec. 8, 2014)).1 These rate schedules Adder component each September to determine if
which a separate charge may be
are formula-based, providing for drought costs differ from those projected in the
sradovich on DSK3GMQ082PROD with NOTICES
incurred. Power Repayment Study and whether an
adjustments to the Drought Adder
[FR Doc. 2017–26375 Filed 12–6–17; 8:45 am] adjustment to the Drought Adder component is
necessary. See 72 FR 64071. The Drought Adder
BILLING CODE 6450–01–P 1 FERC confirmed and approved Rate Order component may be adjusted downward using the
WAPA–166 on a final basis on March 18, 2015, in approved annual Drought Adder adjustment
Docket No. EF15–3–000. See United States process, whereas an incremental upward
Department of Energy, Western Area Power adjustment to the Drought Adder component greater
Administration (Pick-Sloan Missouri Basin than the equivalent of 2 mills/kWh requires a
Program—Eastern Division), 150 FERC ¶ 62,170. public rate process. See 72 FR 64071.
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![57750 Federal Register / Vol. 82, No. 234 / Thursday, December 7, 2017 / Notices
UNITED STATES DEPARTMENT OF River) for its Steel Mill. Title V operating permit issued on September
ENERGY operating permit number 2305–AOP–R0 18, 2013, to Big River Steel, LLC located
WESTERN AREA POWER was issued on September 18, 2013, by in Osceola, Mississippi County,
ADMINISTRATION the ADEQ to Big River for a new steel Arkansas.
mill in Osceola, Mississippi County, The Petitioner requests that the
UPPER GREAT PLAINS REGION Arkansas. EPA’s October 31, 2017, Administrator object to the proposed
PICK-SLOAN MISSOURI BASIN Order responds to a petition submitted operating permit issued by the ADEQ to
PROGRAM—EASTERN DIVISION on October 9, 2013 by the Nucor Steel- Big River based on twelve claims. The
Arkansas and Nucor-Yamato Steel claims are described in detail in Section
SALE OF SURPLUS PRODUCTS Company (the Petitioners), pursuant to IV of the Order. In summary, the issues
(Approved Under Rate Order No. the Clean Air Act (CAA or Act). The Act raised are that: (1) ADEQ conducted an
WAPA–180) provides that a petitioner may ask for inadequate review of background air
judicial review of those portions of the quality data; (2) the PM2.5 modeling is
Effective: Orders that deny objections raised in the deficient because it excluded certain
The first day of the first full billing petitions in the appropriate United areas from the analysis; (3) the PM2.5
period beginning on or after January 1, States Court of Appeals. Any petition modeling is deficient because ADEQ
2018, through December 31, 2022, or for review shall be filed within 60 days failed to include secondary formation of
until superseded by another rate from the date this notice appears in the PM2.5, and instead only included PM2.5
schedule, whichever occurs earlier. Federal Register, pursuant to the Act. directly emitted by the facility; (4)
ADDRESSES: You may review copies of ADEQ’S air quality impacts analysis for
Applicable: the final Order, the petition, and other PM2.5 NAAQS was inadequate because
This rate schedule applies to Eastern supporting information at EPA Region 6, there are discrepancies among different
Division of the Pick-Sloan Missouri 1445 Ross Avenue, Dallas, Texas 75202– modeled PM2.5 annual impact values in
Basin Program marketing and is 2733. or associated with the PM2.5 modeling.;
applicable to the sale of the following P- EPA requests that if at all possible, (5) ADEQ and Big River failed to
SMBP—ED surplus energy and capacity you contact the individual listed in the properly carry out an additional impacts
products; energy, frequency response, FOR FURTHER INFORMATION CONTACT analysis; (6) the emission factors for
regulation, and reserves. If any P- section to view copies of the final Order, natural gas combustion used to issue the
SMBP—ED surplus energy and capacity petition, and other supporting Draft Permit are conflicting; (7) Big
products are available, UGP can make information. You may view the hard River did not adequately demonstrate
the product(s) available for sale, copies Monday through Friday, from the basis for its proposed PM2.5 emission
providing entities enter into a separate 9:00 a.m. to 3:00 p.m., excluding factors; (8) the Big River facility design
agreement(s) with UGP Marketing Office Federal holidays. If you wish to was incomplete in critical ways that
which will specify the terms of sale(s). examine these documents, you should affected the validity of air quality
make an appointment at least 24 hours modeling; (9) the permit does not
Formula Rate: before the visiting day. Additionally, the contain enforceable permit conditions
The charge for each product is final October 31, 2017, Order is that lead to compliance; (10) the Permit
determined at the time of the sale based available electronically at: https:// does not contain adequate monitoring,
on market rates, plus administrative www.epa.gov/sites/production/files/ recordkeeping, and reporting
costs. The customer will be responsible 2017-10/documents/big_river_steel_ requirements to comply with the
for acquiring transmission services response2013.pdf. requirements of 40 CFR 70.6(a)(3)(i)(B)
necessary to deliver the product(s), for FOR FURTHER INFORMATION CONTACT: because it does not provide for a test
which a separate charge may be Dinesh Senghani at (214) 665–7221, method; (11) the Permit does not
incurred. email address: senghani.dinesh@epa.gov appropriately establish BACT
[FR Doc. 2017–26376 Filed 12–6–17; 8:45 am] or the above EPA, Region 6 address. requirements; and (12) ADEQ’s Draft
BILLING CODE 6450–01–P SUPPLEMENTARY INFORMATION: The CAA Permit does not comply with public
affords EPA a 45-day period to review, notice and participation requirements.
and object, as appropriate, to a title V The Order issued on October 31, 2017,
ENVIRONMENTAL PROTECTION operating permit proposed by a state responds to the Petition and explains
AGENCY permitting authority. Sections 307(b) the basis for EPA’s decision.
and 505(b)(2) of the CAA, 42 U.S.C. Dated: December 1, 2017.
[FRL–9970–84–Region 6]
7661d(b)(2), and 40 CFR 70.8(d) Samuel Coleman,
Clean Air Act Operating Permit authorizes any person to petition the Acting Regional Administrator, Region 6.
Program; Petitions for Objection to EPA Administrator, within 60 days after [FR Doc. 2017–26400 Filed 12–6–17; 8:45 am]
State Operating Permit for Big River the expiration of this review period, to BILLING CODE 6560–50–P
Steel, LLC, Osceola, Arkansas object to a title V operating permit if
EPA has not done so. Petitions must be
AGENCY: Environmental Protection based only on objections to the permit
Agency (EPA). that were raised with reasonable FARM CREDIT ADMINISTRATION
ACTION: Notice of final action. specificity during the public comment Sunshine Act Meeting; Farm Credit
sradovich on DSK3GMQ082PROD with NOTICES
period provided by the state, unless the Administration Board
SUMMARY: Pursuant to the Clean Air Act petitioner demonstrates that it was
(CAA), the EPA Administrator signed an impracticable to raise these issues AGENCY: Farm Credit Administration.
Order, dated October 31, 2017, denying during the comment period or unless ACTION: Notice, regular meeting.
a petition asking EPA to object to the the grounds for the issue arose after this
operating permit issued by the Arkansas period. SUMMARY: Notice is hereby given,
Department of Environmental Quality EPA received the petition from the pursuant to the Government in the
(ADEQ) to Big River Steel, LLC (Big Petitioners on October 9, 2013, for the Sunshine Act, of the regular meeting of
VerDate Sep<11>2014 18:50 Dec 06, 2017 Jkt 244001 PO 00000 Frm 00048 Fmt 4703 Sfmt 4703 E:\FR\FM\07DEN1.SGM 07DEN1](https://thefederalregister.org/doc/82_FR_57976/page/9.svg)
Document Created: 2017-12-07 00:34:52
Document Modified: 2017-12-07 00:34:52
| 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 order concerning firm power, firm peaking power, and sale of surplus product formula rates. | |
| Dates | The Rate Schedules P-SED-F13, P-SED-FP13, and P-SED-M1 are effective on the first day of the first full billing period beginning on or after January 1, 2018, and will remain in effect through December 31, 2022, pending confirmation and approval by Federal Energy Regulatory Commission (FERC) on a final basis or until superseded. | |
| Contact | Mr. Jody S. Sundsted, Acting Regional Manager, Upper Great Plains Region, Western Area Power Administration, 2900 4th Avenue North, Billings, MT 59101-1266, telephone (406) 255- 2800, or Ms. Linda Cady-Hoffman, Rates Manager, Upper Great Plains Region, Western Area Power Administration, 2900 4th Avenue North, Billings, MT 59101-1266, telephone (406) 255-2920, email [email protected] | |
| FR Citation | 82 FR 57742 |
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