Federal Register Vol. 80, No.184,

This Record of Decision (ROD) and Approved Land Management Plan (LMP) Amendments for the Rocky Mountain Region Greater Sage-Grouse (GRSG) sub-regions of Northwest Colorado and Wyoming were developed through a collaborative planning process and incorporate land-use plan level conservation measures into existing Forest Service LMPs to conserve, enhance, and restore GRSG and its habitat by reducing, eliminating, or minimizing threats to GRSG and its habitat. The ROD and Approved LMP Amendments include management direction that limits or eliminates new surface disturbance in GRSG Priority Habitat Management Areas, while minimizing disturbance in GRSG General Habitat Management Areas. In addition to establishing protective management direction, the Approved LMP Amendments establish a suite of management provisions, such as the establishment of disturbance limits, GRSG habitat objectives, mitigation requirements, monitoring protocols, and adaptive management triggers and responses, as well as other conservation measures throughout the range. The cumulative effect of these conservation measures is to protect, improve, and restore GRSG habitat across the remaining range of the species in the Rocky Mountain Region and provide greater certainty that Forest Service activities and authorizations in GRSG habitat will lead to conservation of GRSG and its habitat as well as other sagebrush-steppe associated species in the Region.

The ROD and Approved LMP Amendments amend the following Forest Service LMPs:

The Northwest Colorado and Wyoming Draft Land Use Plan Amendments (LUPAs)/Draft Environmental Impact Statements (EISs) and Proposed LUPAs/Final EISs also included proposed GRSG management direction on Bureau of Land Management (BLM) public lands. However, the BLM completed a separate ROD and Resource Management Plan Amendments/Revisions under BLM planning authorities. Management decisions within the Forest Service ROD and Approved LMP Amendments apply only to National Forest System lands. Notice of Availability for the Rocky Mountain Region GRSG Proposed LUPs/Final EISs were published in the Federal Register on May 29, 2015, which initiated a 30-day protest period.

The BLM and Forest Service received 55 timely and valid protest submissions for all Rocky Mountain region Proposed LUPAs/Final EISs. After careful consideration of the all issues raised in these protests, the Deputy Chief for the National Forest System concluded that the responsible planning team followed all applicable laws, regulations, and policies and considered all relevant resource information and public input in developing the Proposed LUPs/Final EISs. For a full description of the issues raised during the protest period and how they were addressed, please refer to the Protest Resolution Reports for the Northwest Colorado and Wyoming Proposed LUPAs/Final EISs. These Reports, which include two Forest Service Proposed LMP amendments for Northwest Colorado and Wyoming, are available at the following Web site: http://www.blm.gov/wo/st/en/prog/planning/planning_overview/protest_resolution/protestreports.html.

The preferred alternatives, as presented in the Draft LUP Amendments/EISs and further developed in the Proposed LUP Amendments/Final EISs as the Proposed Plan Amendments, were selected in the ROD as the Approved LMP Amendments with some minor clarifications.

Copies of the Northwest Colorado GRSG ROD and Approved LMP Amendment are available upon request and are available for public inspection at:

This Record of Decision (ROD) and Approved Land Management Plan (LMP) Amendments for the Great Basin Region Greater Sage-Grouse (GRSG) sub-regions of Idaho and Southwestern Montana, Nevada, and Northeast California, and Utah were developed through a collaborative planning process and incorporate land-use plan level conservation measures into existing Forest Service LMPs to conserve, enhance, and restore GRSG and its habitat by reducing, eliminating, or minimizing threats to GRSG and its habitat. The ROD and Approved LMP Amendments include management direction that limits or eliminates new surface disturbance in GRSG Priority Habitat Management Areas, while minimizing disturbance in GRSG General Habitat Management Areas. In addition to establishing protective land use allocations, the Approved LMP Amendments establish a suite of management provisions, such as the establishment of disturbance limits, GRSG habitat objectives, mitigation requirements, monitoring protocols, and adaptive management triggers and responses, as well as other conservation measures throughout the range. The cumulative effect of these conservation measures is to protect, improve, and restore GRSG habitat across the remaining range of the species in the Great Basin Region and provide greater certainty that Forest Service activities and authorizations in GRSG habitat in the Great Basin Region will lead to conservation of the GRSG and its habitat as well as other sagebrush-steppe associated species in the Region.

The ROD and LMP amendments amend the following Forest Service LMPs:

The Idaho and Southwestern Montana, Nevada, and Northeast California, and Utah Draft Land Use Plan Amendments (LUPAs)/Draft Environmental Impact Statements (EISs) and Proposed LUPAs/Final EISs included proposed GRSG management direction on Bureau of Land Management (BLM) public lands. However, the BLM completed a separate ROD and Resource Management Plan Amendments under BLM planning authorities. Management decisions within this ROD and Approved LMP Amendments apply only to National Forest System lands. There were no National Forest System lands involved in this effort in Northeast California.

A Notice of Availability for the Great Basin Region GRSG Proposed LMP Amendments/Final EISs for the Idaho and Southwest Montana, Nevada, and Northeast California, Oregon, and Utah sub-regions was published in the Federal Register on May 29, 2015, which initiated a 30-day protest period.

The BLM and Forest Service received 102 timely and valid protest submissions for all the Great Basin Region Proposed LUPAs/Final EISs. After careful consideration of all the issues raised in these protests, the Deputy Chief for the National Forest System concluded the responsible planning team followed all applicable laws, regulations, and policies and considered all relevant resource information and public input in developing the Proposed LMPs/Final EISs. For a full description of the issues raised during the protest period and how they were addressed, please refer to the Protest Resolution Reports for the Idaho and Southwest Montana, Nevada and Northeast California, and Utah Proposed LUPAs/Final EISs. These Reports, which include three Forest Service Proposed LMPs for Idaho and Southwest Montana, Nevada, and Utah, are available at the following Web site: http://www.blm.gov/wo/st/en/prog/planning/planning_overview/protest_resolution/protestreports.html.

The preferred alternatives, as presented in the Draft LUPA/Draft EISs and and further developed in the Proposed LUPAs/Final EISs as the Proposed Plan Amendment, were selected in the ROD as the Approved LMP Amendments with some minor clarifications.

Copies of the Idaho and Southwest Montana GRSG ROD and Approved LMP Amendment are available upon request and are available for public inspection at:

Copies of the Nevada GRSG ROD and Approved LMP amendment are available upon request and are available for public inspection at:

Copies of the Utah GRSG ROD and Approved LMP amendment are available upon request and are available for public inspection at:

The purpose of the meeting is to:

1. Make decisions on proposals submitted for FY2015 Title II funds; and

2. Establish additional meeting dates, if necessary.

The meeting is open to the public. The agenda will include time for people to make oral statements of three minutes or less. Individuals wishing to make an oral statement should request in writing by October 6, 2015, to be scheduled on the agenda. Anyone who would like to bring related matters to the attention of the committee may file written statements with the committee staff before or after the meeting. Written comments and requests for time to make oral comments must be sent to Kent Wellner, Designated Federal Officer, 3106 Pierce Parkway, Suite D, Springfield, Oregon 97477; by email to [email protected], or via facsimile to 541-225-6228.

Meeting Accommodations: If you are a person requiring reasonable accommodation, please make requests in advance for sign language interpreting, assistive listening devices or other reasonable accommodation for access to the facility or proceedings by contacting the person listed in the section titled FOR FURTHER INFORMATION CONTACT. All reasonable accommodation requests are managed on a case by case basis.

The Committee was established September 2, 1999. The Committee advises the Director of BEA on matters related to the development and improvement of BEA's national, regional, industry, and international economic accounts, especially in areas of new and rapidly growing economic activities arising from innovative and advancing technologies, and provides recommendations from the perspectives of the economics profession, business, and government. This will be the Committee's twenty-ninth meeting.

Public Participation: This meeting is open to the public. Because of security procedures, anyone planning to attend the meeting must contact Gianna Marrone of BEA at (202) 606-9633 in advance. The meeting is physically accessible to people with disabilities. Requests for foreign language interpretation or other auxiliary aids should be directed to Gianna Marrone at (202) 606-9633.

On February 13, 2015, the United States informed the DSB that the United States intends to implement the DSB's recommendations and rulings in WTO/DS436. The segments of the proceeding subject to implementation are as follows:

In accordance with Section 129(b)(1) of the URAA, the Department consulted with the Office of the United States Trade Representative, and on August 21, 2015, pursuant to those consultations, opened segments in the CVD administrative reviews at issue to commence administrative actions to comply with the DSB's recommendations and rulings. Each segment will consist of a separate administrative record with its own administrative protective order. In accordance with 19 CFR 351.305(b), interested parties may request access to business proprietary information in the segment of the proceeding to which they are participating. For each of these Section 129 segments, we may request additional information and we may conduct verification of such information. Consistent with Section 129(d) of the URAA, the Department will issue preliminary results in each of the Section 129 segments, the Department will provide interested parties with an opportunity to provide written comments on those preliminary results, and the Department may hold a hearing.

In accordance with the Department's regulations, all submissions to the Department must be filed electronically using Enforcement and Compliance's Antidumping and Countervailing Duty Centralized Electronic Service System (ACCESS). An electronically-filed document must be received successfully in its entirety by the time and date it is due. Documents excepted from the electronic submission requirements must be filed manually (i.e., in paper form) with Enforcement and Compliance's APO/Dockets Unit, Room 18022, U.S. Department of Commerce, 14th Street and Constitution Avenue NW., Washington, DC 20230, and stamped with the date and time of receipt by the applicable deadlines.1

Pursuant to 19 CFR 351.103(d)(l), to be included on the public service list for the Section 129 determination for the aforementioned proceedings, all interested parties, including parties that were part of the public service list in the underlying segments of the proceeding and any parties otherwise notified of the Department's commencement of these Section 129 proceedings, must file a letter of appearance. The letter of appearance must be filed separately from any other document (with the exception of an application for administrative protective order (APO) access; parties applying for and granted APO access would automatically be on the public service list). Parties wishing to enter an appearance or submit information with regard to these proceedings must upload their filing(s) to each relevant case number. Additionally, for each submission made in ACCESS, parties must select “S 129-SEC 129” as the segment, and enter “DS436-“2004” “DS436-2006,” “DS436-2007” or “DS436-2008” as appropriate in the segment specific information field.

Factual information is defined in 19 CFR 351.102(b)(21) as: (i) Evidence submitted in response to questionnaires; (ii) evidence submitted in support of allegations; (iii) publicly available information to value factors under 19 CFR 351.408(c) or to measure the adequacy of remuneration under 19 CFR 351.511(a)(2); (iv) evidence placed on the record by the Department; and (v) evidence other than factual information described in (i)-(iv). The regulation requires any party, when submitting factual information, to specify under which subsection of 19 CFR 351.102(b)(21) the information is being submitted and, if the information is submitted to rebut, clarify, or correct factual information already on the record, to provide an explanation identifying the information already on the record that the factual information seeks to rebut, clarify, or correct. Time limits for the submission of factual information are addressed in 19 CFR 351.301, which provides specific time limits based on the type of factual information being submitted. Parties should review the regulations prior to submitting factual information in these segments.

Parties may request an extension of time limits before the expiration of a time limit established under Part 351, or as otherwise specified by the Secretary. In general, an extension request will be considered untimely if it is filed after the expiration of the time limit established under Part 351 expires. For submissions that are due from multiple parties simultaneously, an extension request will be considered untimely if it is filed after 10:00 a.m. on the due date. Under certain circumstances, we may elect to specify a different time limit by which extension requests will be considered untimely for submissions which are due from multiple parties simultaneously. In such a case, we will inform parties in the letter or memorandum setting forth the deadline (including a specified time) by which extension requests must be filed to be considered timely. An extension request must be made in a separate, stand-alone submission; under limited circumstances we will grant untimely-filed requests for the extension of time limits. Review Extension of Time Limits; Final Rule, 78 FR 57790 (September 20, 2013), available at http://www.thefederalregister.org/fdsys/pkg/FR-2013-09-20/html/2013-22853.htm prior to submitting factual information in these segments.

Any party submitting factual information in an antidumping (AD) or CVD proceeding must certify to the accuracy and completeness of that information.2 Parties are hereby reminded that revised certification requirements are in effect for company/government officials, as well as their representatives. Investigations initiated on the basis of petitions filed on or after August 16, 2013, and other segments of any AD or CVD proceedings initiated on or after August 16, 2013, should use the formats for the revised certifications provided at the end of the Final Rule. 3 The Department intends to reject factual submissions if the submitting party does not comply with the applicable revised certification requirements.

Interested parties must submit applications for disclosure under APO in accordance with 19 CFR 351.305. On January 22, 2008, the Department published Antidumping and Countervailing Duty Proceedings: Documents Submission Procedures; APO Procedures, 73 FR 3634 (January 22, 2008). Parties wishing to participate in these investigations should ensure that they meet the requirements of these procedures (e.g., the filing of letters of appearance as discussed at 19 CFR 351.103(d)).

This notice is published in accordance with Section 129(b)(1) of the URAA.

The petitioner in this investigation is the American Sugar Coalition and its members (Petitioners).1 In addition to the Government of Mexico (GOM), the mandatory respondents in this investigation are Fondo de Empresas Expropiadas del Sector Azucarero (FEESA) and Ingenio Tala S.A. de C.V. and certain affiliated companies owned by Grupo Azucarero Mexico S.A. de C.V. (collectively, the GAM Group). The period of investigation (POI) is January 1, 2013, through December 31, 2013.

The Department published its affirmative Preliminary Determination on September 2, 2014.2 On December 19, 2014, the Department and a representative of the GOM signed an agreement suspending this CVD investigation.3 Pursuant to timely requests for continuation filed on January 16, 2015,4 the Department published notice of continuation of the investigation on May 4, 2015.5 Subsequently, on June 18, 2015, the Department issued a post-preliminary analysis memorandum.6 A complete summary of the events that occurred since publication of the Preliminary Determination, as well as a full discussion of the issues raised by parties for this final determination, may be found in the “Issues and Decision Memorandum for the Final Affirmative Determination in the Countervailing Duty Investigation of Sugar from Mexico” (Issues and Decision Memorandum),7 which is dated concurrently with and hereby adopted by this notice. The Issues and Decision Memorandum is a public document and is available electronically via Enforcement and Compliance's Antidumping and Countervailing Duty Centralized Electronic Service System (ACCESS). Access is available to registered users at http://access.trade.gov and to all parties in the Central Records Unit, room B8024 of the Department's main building. In addition, a complete version of the Issues and Decision Memorandum can be accessed at http://enforcement.trade.gov/frn/. The signed Issues and Decision Memorandum and the electronic version are identical in content.

The product covered by this investigation is sugar from Mexico. Since the Preliminary Determination, the Department has updated the scope of the investigation. For a discussion of these changes, see the “Scope Comments” section of the Issues and Decision Memorandum and, for a complete description of the scope, see Appendix I to this notice.

The subsidy programs under investigation and the issues raised in the case briefs and rebuttal briefs submitted by interested parties in this proceeding are discussed in the Issues and Decision Memorandum. A list of the issues raised by parties and responded to by the Department in the Issues and Decision Memorandum is attached at Appendix II to this notice.

Based on our analysis of the comments received and our findings at verification, we made certain changes to the respondents' subsidy rate calculations since the Preliminary Determination and our post-preliminary analysis. These changes are discussed in the “Analysis of Programs” section of the Issues and Decision Memorandum. As discussed in the Issues and Decision Memorandum, for purposes of this final determination, the Department relied, in part, on facts available when necessary information was not available on the record.8

In accordance with 705(c)(1)(B)(i)(1) of the Tariff Act of 1930, as amended (the Act), the Department calculated a countervailable subsidy rate for each individually investigated exporter/producer of the subject merchandise. Consistent with sections 705(c)(1)(B)(i)(I) and 705(c)(5)(A) of the Act, the Department also calculated an estimated “all others” rate for exporters and producers not individually investigated. Section 705(c)(5)(A)(i) of the Act provides that the “all others” rate will be equal to the weighted-average of the countervailable subsidy rates, excluding de minimis rates and rates determined entirely under section 776 of the Act, established for individually investigated exporters and producers. Because the weighted-average countervailable subsidy rates calculated for FEESA and the GAM Group are not de minimis and are not based entirely on section 776 of the Act as facts available, the Department has estimated the “all others” rate in this final determination by weight-averaging the weighted-average countervailable subsidy rates calculated for FEESA and the GAM Group.

We determine the total estimated countervailable subsidy rates to be:

In accordance with 19 CFR 351.224(b), we will disclose the calculations performed within five days of any public announcement of this notice.

As noted above, the Department signed a Suspension Agreement in this investigation on December 19, 2014. On March 27, 2015, following a review of the Suspension Agreement by the International Trade Commission (ITC), the Department, in accordance with sections 704(h)(3)(A) and (B) of the Act, instructed Customs and Border Protection (CBP) to terminate the suspension of liquidation of all entries of sugar from Mexico and to refund any collected cash deposits without regard to countervailing duties.9 Notwithstanding the continuation and completion of the investigation, as the Suspension Agreement continues to be in place, the Department will not instruct CBP to suspend liquidation or to assess cash deposits at the countervailing duty rates noted above unless the Suspension Agreement is terminated.

The Department's regulations provide that the Secretary will publish in the Federal Register a list of scope rulings on a quarterly basis.1 Our most recent notification of scope rulings was published on June 16, 2015.2 This current notice covers all scope rulings and anticircumvention determinations made by Enforcement and Compliance between April 1, 2015, and June 30, 2015, inclusive. Subsequent lists will follow after the close of each calendar quarter.

Requestor: All Points Industries Inc. (“All Points”); All Points' cleats are within the scope of the orders on aluminum extrusions from the PRC because they are single-piece aluminum extrusions without accessories, attachments, fasteners, or other non-extruded parts of aluminum or any other material, and match the physical description of subject merchandise; April 2, 2015.

Requestor: Guardian Fall Protection, Inc.; window anchors are outside the scope of the orders because they represent finished merchandise containing aluminum extrusions as parts that are fully and permanently assembled and completed at the time of entry; April 21, 2015.

Requestor: Unger Enterprises Inc. (“Unger”); Unger's pole handles, consisting of aluminum extrusion tubes, polypropylene hand grips, polypropylene tool and accessory attachment heads, and “optiloc” plastic locking collars, are outside the scope of the orders on aluminum extrusions from the PRC under the finished goods exclusion because they are finished goods containing aluminum extrusions as parts that are fully and permanently assembled and completed at the time of entry; April 22, 2015.

Requestor: Ikea Supply AG (“IKEA”); IKEA's cabinet/drawer handles are within the scope of the orders on aluminum extrusions from the PRC because the cabinet/drawer handles are comprised solely of an aluminum extrusion that matches the description of subject merchandise and fasteners (i.e., screws and nuts); April 27, 2015.

Requestor: Ikea Supply AG (“IKEA”); IKEA's towel racks are within the scope of the orders on aluminum extrusions from the PRC because the towel racks are comprised solely of an aluminum extrusion that matches the description of subject merchandise and fasteners; April 27, 2015.

Requestor: Streamlight, Inc. (“Streamlight”); Streamlight's heat sink parts for LED lamps are within the scope of the orders on aluminum extrusions from the PRC because the heat sink parts for LED lamps do not meet the two criteria to qualify for the finished heat sink exclusion from the orders; May 14, 2015.

Requestor: TSS, Inc.; the LT-10H2 Wind Sign Frame is outside the scope of the orders because it is finished merchandise containing aluminum extrusions as parts that are fully and permanently assembled and completed at the time of entry; June 16, 2015.

Requestor: Suqian Langer International Trade Co., Ltd. (“Suqian Langer”); Suqian Langer's artist canvases are outside the scope of the order because the weaving and priming of the canvases, which impart the artist canvases' essential characteristics, are performed in India and not the People's Republic of China; May 26, 2015.

Requestor: Unique Fire Stop Products, Inc. (UFS); Smooth Fire Stop Sleeve System products are not within the scope, which states that covered products are “generally known as standard and structural pipe.” UFS' product could not be used for the purposes for which standard or structural pipe are used; June 10, 2015.

Requestor: National Public Seating (NPS); NPS' Banquet Stack Chair Dolly is within the scope of the order because it possesses all the essential physical characteristics of subject hand trucks; April 6, 2015.

Requestor: Bond Street Ltd.; the Bond Cart Model 390008 is within the scope of the order because it possesses all the essential physical characteristics of subject hand trucks; April 22, 2015.

Requestor: Bassett Mirror Company, Inc.; Reflections and Murano chairside chests are outside the scope of the antidumping duty order because of their limited storage space and characteristics consistent with end tables or occasional tables; April 30, 2015.

Requestor: Rodacciai S.p.A. and Roda Specialty Steel, Inc.; Cold-finished stainless steel bar manufactured through cold-drawing and other finishing steps in Italy using stainless steel wire rod imported from Spain is not within the scope of the antidumping duty order; May 12, 2015.

Requestor: Rodacciai S.p.A. and Roda Specialty Steel, Inc.; Cold-finished stainless steel bar manufactured through cold-drawing and other finishing steps in Italy using stainless steel wire rod imported from Spain is not within the scope of the antidumping duty order; May 12, 2015.

Interested parties are invited to comment on the completeness of this list of completed scope and anticircumvention inquiries. Any comments should be submitted to the Deputy Assistant Secretary for AD/CVD Operations, Enforcement and Compliance, International Trade Administration, 14th Street and Constitution Avenue NW., APO/Dockets Unit, Room 1870, Washington, DC 20230.

This notice is published in accordance with 19 CFR 351.225(o).

On November 3, 2014, the Department published in the Federal Register the Preliminary Determination of sales at LTFV in the antidumping duty investigation of sugar from Mexico.1 The following events occurred since the Preliminary Determination was issued. Between December 3 and 16, 2014, we conducted sales and cost verifications of the two respondents in this investigation, FEESA 2 and the GAM Group.3 The verification reports were issued between January 29 and March 31, 2015.

On December 19, 2014, the Department and a representative of the producers/exporters accounting for substantially all imports of sugar from Mexico, the Camara Nacional de Las Industrias Azucarera y Alcoholera, signed a suspension agreement in this investigation.4 On January 8, 2015, Imperial Sugar (Imperial) and AmCane Sugar LLC (AmCane) each notified the Department that they had petitioned the International Trade Commission (ITC) to conduct a review to determine whether the injurious effects of the imports of the subject merchandise are eliminated completely by the AD Suspension Agreement (a section 734(h) review).5 Additionally, on January 16, 2015, AmCane and Imperial submitted timely requests for the continuation of the instant investigation.6 On March 19, 2015, in a unanimous vote, the ITC found that the AD Suspension Agreement eliminated completely the injurious effects of imports of sugar from Mexico. On the same day, the Department announced that it would issue a decision regarding continuation of the investigations promptly after the ITC made its views and findings available.7 On March 24, 2015, the ITC notified the Department of its determination, and on April 10, 2015, provided a report of its views and findings to the Department.8 Subsequently, on April 24, 2015, the Department determined that AmCane and Imperial had standing to request continuation of this investigation and, as a result, published a continuation notice on May 4, 2015.9 Accordingly, on May 4, 2015, the Department announced the briefing schedule. Consistent with the schedule, case briefs were filed on May 29, 2015, and rebuttal briefs on June 12, 2015.

The product covered by this investigation is sugar from Mexico. Since the Preliminary Determination, the Department has updated the scope of the investigation. For a discussion of these changes, see “Scope Comments” section of the Issues and Decision Memorandum 10 and, for a complete description of the scope of the investigation, see Appendix I to this notice.

All issues raised in the case and rebuttal briefs by parties in this investigation are addressed in the Issues and Decision Memorandum, which is hereby adopted by this notice. A list of the issues raised is attached to this notice as Appendix II. The Issues and Decision Memorandum is a public document and is on file electronically via Enforcement and Compliance's Antidumping and Countervailing Duty Centralized Electronic Service System (ACCESS). ACCESS is available to registered users at http://access.trade.gov and it is available to all parties in the Central Records Unit, room B8024 of the main Department of Commerce building. In addition, a complete version of the Issues and Decision Memorandum can be accessed directly at http://enforcement.trade.gov/frn/. The signed and electronic versions of the Issues and Decision Memorandum are identical in content.

Based on our analysis of the comments received and our findings at verification, we made certain changes to the margin calculations. For a discussion of these changes, see the “Margin Calculations” section of the Issues and Decision Memorandum.

As provided in section 782(i) of the Act, in December, 2014, we verified the sales and cost information submitted by FEESA and the GAM Group for use in our final determination. We used standard verification procedures including an examination of relevant accounting and production records, and original source documents provided by the two respondents.11

The Atlantic Coastal Act, 16 U.S.C. 5101 et seq., sets forth a non-compliance review and determination process that is triggered when the Commission finds that a State has not implemented measures specified in an Interstate Fishery Management Plan (ISFMP) and refers that determination to the Secretary for review and potential concurrence.

The Atlantic Coastal Act's non-compliance process involves two stages of decision-making. In the first stage, the Secretary (delegated to the AA) must make two findings: (1) Whether the State in question has failed to carry out its responsibility under the Commission's ISFMP; and if so (2) whether the measures that the State failed to implement and enforce are necessary for the conservation of the fishery in question. These initial findings must be made within 30 days after receipt of the Commission's non-compliance referral and consequently, this first stage of decision-making is referred to as the 30-Day Determination.

A positive 30-Day Determination triggers the second stage of Atlantic Coastal Act non-compliance decision-making, which occurs contemporaneous with the first decision. That is, if the AA determines non-compliance in the first stage, the Act mandates that a moratorium on fishing in State waters in the fishery in question occur. The timing of the moratorium, however, is at the discretion of the AA, so long as it is implemented within six (6) months of the 30-Day Determination. In other words, although the implementation of the moratorium is non-discretionary, the AA has the discretion to decide when the moratorium will be implemented subject to the Act's six (6) month deadline.

On August 6, 2015, the Commission found that the State of Delaware is out of compliance with the Commission Plan. Specifically, the Commission found that Delaware has not implemented regulations that are necessary to rebuild the depleted American eel stock, and to ensure sustainable commercial and recreational harvest while preventing over-harvest of any eel life stage. The required measures that Delaware failed to implement are as follows:

The following measures apply to all current yellow eel commercial fisheries. The development of any future yellow eel fisheries would be subject to the following measures:

Minimum size and mesh requirements—It is generally accepted that American eel in the northern portion of the species' range are larger than eel in the southern end of the range. However, there is not enough information at this time to develop regional or state specific maximum sizes for the coast. Nonetheless, there is growing concern about the development of fisheries on small yellow eels and an increase in the minimum size is a means to prevent this fishery from developing further. The benefit of effective gear restrictions is smaller eels are not landed, thus eliminating the need for harvesters to handle these fish or enforcement having to measure fish. No gear requirements are sought to exclude larger eels from pots at this time because only a low number of silver eels are caught in pot fisheries. Gear restrictions that are instituted should be monitored for effectiveness. States and jurisdictions are required to adopt a nine (9) inch minimum size limit for all yellow eel fisheries. Harvesters are required to sort their catch and discard eels smaller than the size limit.

States and jurisdictions are required to implement a 1/2” by 1/2” minimum on the mesh size used in commercial yellow eel pots. States may allow, for up to three years starting January 1, 2014, the use of a 4 by 4 inch escape panel constructed of a mesh size of at least 1/2” by 1/2” inch mesh in order to reduce the financial burden of gear changes on the fishery.

The following measures apply to all current yellow eel recreational fisheries. In order to minimize the chance of excessive recreational harvest, as well as circumvention of commercial eel regulations, the ASMFC member states/jurisdictions shall establish uniform possession limits for recreational fisheries. States and jurisdictions are required to adopt a nine (9) inch minimum size limit for all recreational fisheries.

Recreational Bag Limit—Given the interest to have all fishery sectors contribute to conservation measures under Addendum III all states and jurisdictions are required to implement a daily recreational bag limit of 25 fish per day per angler.

Party/charter (for hire) exemption—Crew and captain involved in party/charter (for-hire) employment on party/charter (for-hire) activities are exempt from recreational bag limit reduction. Crew members involved in for-hire employment are allowed to maintain the current 50 fish per day bag limit for bait purposes during fishing, as specified under the American Eel ISFMP.

The Commission's Plan required all member States to implement the plan's eel regulations by January 1, 2014. As of August 6, 2015, Delaware still had not implemented the required actions. During both the Commission's August 5, 2015, American Eel Management Board meeting and its August 6, 2015, Policy and Business Board meetings, Delaware agreed with the Boards' determinations that they were not in compliance with the Plan.

The Commission forwarded its findings of their August 6th vote in a formal non-compliance referral letter that the Secretary received on August 19, 2015. In response to receipt of this letter, NMFS began the Atlantic Coastal Act's 30-day determination clock. On August 21, 2015, NMFS sent letters to the State of Delaware, the Mid-Atlantic Fishery Management Council, the U.S. Fish & Wildlife Service (USFWS), and to the Commission, advising them of the Atlantic Coastal Act's non-compliance process, inviting them to provide commentary on the issue, and in the case of Delaware, inviting the State to meet with NMFS to present its position in person or provide written comments on the Commission findings. NMFS also advised the public of the referral, and invited comments in a Federal Register notice dated August 27, 2015 (80 FR 166).

On September 2, 2015, Delaware representatives met with NMFS staff via conference call. During this meeting, Delaware agreed that it was out of compliance and that it did not contest the conservation necessity of the Commission's American eel measures. Delaware described its legal and regulatory framework for eel, its eel fishery, and confirmed its intent to finalize legislation to comply with measures identified in Addendum III in January 2016 irrespective of any Federal action. Delaware followed up that meeting with a letter on September 11, 2015, that provided additional information on Delaware's past efforts and current plans to comply with the Plan, previous and current eel conservation measures and eel fisheries. NMFS received one public comment in response to the referral of non-compliance. That comment supported a full moratorium, albeit without articulating any background or factual support. The USFWS also provided a letter with comments concurring with the Commission finding that the State of Delaware is currently out of compliance with the ISFMP for American Eel. In addition, the USFWS has been undertaking an extensive status review for the American eel to determine if adding the species to the Federal list of endangered and threatened wildlife list is warranted. A petition to list American eel was submitted by the Council for Endangered Species Act Reliability. A 12-month finding as to whether the listing is warranted is expected by September 30, 2015.

NMFS' findings in this matter support a positive 30-Day Determination of non-compliance. The best available science suggests that American eel are depleted and that management measures are necessary to conserve the species. Specifically, the 2012 Benchmark American Eel Stock Assessment indicated that the American eel stock has declined in recent decades and the prevalence of significant downward trends in multiple surveys across the coast is cause for concern. The measures that Delaware failed to adopt were recommended by the Commission in Addendum III to respond to the stock assessment's findings. Delaware voted to approve those measures in 2013 during the Addendum III process and the state agrees even now that the measures are necessary for conservation. NMFS also agrees.

NMFS recommends that the required moratorium begin on March 18, 2016. This moratorium would prohibit, in Delaware waters, the possession of American eel (all life stages). We chose the March implementation date after consulting with the relevant staff from Delaware, and reviewing the facts of this situation, including the Commission deliberations from this past August. Based upon our analysis, we found that a March implementation date is appropriate for two principle reasons. First, a March 18th closure date will give Delaware the time necessary for its legislature to bring these regulations back into compliance. Second, although the involved measures are necessary for conservation, the immediacy of that need is less critical given that Delaware's fall eel fishery appears to not target eels that are the subject of Addendum III's protection.

Delaware indicated to us that they expect to have appropriate regulations protecting American eel in place by early next year. If the State of Delaware does enact such measures, and the Commission determines that the measures are compliant with the Plan, under the Act, the Commission would immediately notify the Secretary that the state of Delaware is in compliance with the Plan. If NMFS concurs, the moratorium in the state waters of Delaware will be rescinded. If Delaware is unable to put in place appropriate regulations prior to March 18, 2016, then a Federal moratorium on eel fishing in Delaware waters would be immediately implemented and continue until the Secretary concurs with a determination from the Commission that the state of Delaware has come into compliance with the Plan.

The positive 30-day finding triggers the moratorium prohibitions set forth in the Atlantic Coastal Act, 16 U.S.C. 5106(e). Accordingly, on March 18, 2016, NMFS will implement an American eel moratorium for in Delaware state waters. At that time, it will be unlawful to do the following:

(1) Engage in fishing for American eel within the waters of the Delaware (Note: Under the Atlantic Coastal Act, the definition of “fishing” includes landing and/or possessing);

(2) Land, attempt to land, or possess American eel that are caught, taken, or harvested in violation of the moratorium;

(3) Fail to return to the water immediately, with a minimum of injury, any American eel in Delaware waters that are taken incidental to fishing for species other than those to which the moratorium applies;

(4) Refuse to permit any officer authorized to enforce the provisions of this moratorium to board a fishing vessel subject to such person's control for purposes of conducting any search or inspection in connection with the enforcement of this chapter;

(5) Forcibly assault, resist, oppose, impede, intimidate, or interfere with any such authorized officer in the conduct of any search or inspection under this moratorium;

(6) Resist a lawful arrest for any act prohibited by this moratorium;

(7) Ship, transport, offer for sale, sell, purchase, import, or have custody, control, or possession of, any fish taken or retained in violation of this moratorium; or

(8) Interfere with, delay, or prevent, by any means, the apprehension or arrest of another person, knowing that such other person has committed any act prohibited by this moratorium.

This declaration of a moratorium is consistent with the Atlantic Coastal Act at 16 U.S.C. 5106 insofar as Delaware has been found to have failed to carry out its responsibilities under the Commission's American Eel Plan and the measures that Delaware has failed to implement and enforce are necessary for the conservation of the American eel fishery. Further, the moratorium prohibits fishing, possessing and/or landing American eel within Delaware state waters and is being implemented within six months of the agency findings.

The declaration of a moratorium is consistent with the Administrative Procedures Act at 5 U.S.C. 555 insofar as Delaware was given prompt notice of the Commission's non-compliance referral and was given an opportunity to meet with the agency and provide comments on this matter. Further, the agency has immediately notified Delaware of the agency's determination in this matter. Additionally, NMFS provided notice to the public of this compliance action in a notice in the Federal Register dated (80 FR 166, August 27, 2015). NMFS received one comment in response to that notice suggesting that Delaware be found out of compliance and that a moratorium be implemented. The comment did not provide any further detail. NMFS' present action is consistent with the commenter's suggested outcome.

NMFS finds that public comment is impracticable and contrary to the public interest, not only because the rigid statutory time lines makes such impracticable and would impermissibly delay mandatory agency action, but also because the issue has been considerably vetted in public forums, such as before the Delaware General Assembly and the Commission in the months prior to the referral. Nevertheless, NMFS did notify the public of this action in its Federal Register Notice (80 FR 166; August 27, 2015). NMFS received one comment, which supported a moratorium and is described above.

The declaration of moratorium does not trigger the analytical requirements of the Regulatory Flexibility Act, 5 U.S.C. 601 et seq. because the action was not the result of notice and comment rulemaking under Section 553 of the Administrative Procedures Act.

The declaration of a moratorium does not fall under review under Executive Order 12866 insofar as the moratorium is not a regulatory action of the agency but is an action mandated by Congress upon the findings of certain conditions precedent set forth in the Atlantic Coastal Act, which also prescribes the nature and extent of the moratorium. Nevertheless, the agency has determined that this action is not significant for the purpose of E.O. 12866. The fishery is small and a moratorium is not expected to materially adversely affect the economy or have an impact of over $100 million. The matter creates no serious inconsistency with actions by other agencies and is not expected to have material budgetary impacts.

The moratorium is not the result of a policy formulated or implemented by the agency, but instead is the result of the application of found facts to the Congressional standards set forth in the Atlantic Coastal Act and as such, the declaration does not implicate federalism in the manner contemplated by Executive Order 13132. The agency, however, has nevertheless consulted, to the extent practicable, with appropriate state and local administrative and law enforcement officials to address the principles, criteria, and requirements of E.O. 13132.

This request is for a reinstatement without change. The National Marine Fisheries Service (NMFS) proposes to collect economic information from golden-crab landing commercial fishermen in the United States (U.S.) South Atlantic region. The data gathered will be used to evaluate the likely economic impacts of management proposals. In addition, the information will be used to satisfy legal mandates under Executive Order 12898, the Magnuson-Stevens Fishery Conservation and Management Act (U.S.C. 1801 et seq.), the Regulatory Flexibility Act, the Endangered Species Act, and the National Environmental Policy Act, and other pertinent statues.

A standardized survey will be administered via in-person, telephone and/or mail to all fishermen participating in the fishery.

OMB Number: 0648-0631.

Form Number: None.

Type of Review: Regular submission (reinstatement without change of a previously approved information collection).

Affected Public: Business or other for-profit organizations.

Estimated Number of Respondents: 9.

Estimated Time per Response: 1 hour.

Estimated Total Annual Burden Hours: 9.

Estimated Total Annual Cost to Public: $0 in recordkeeping/reporting costs.

Comments are invited on: (a) Whether the proposed collection of information is necessary for the proper performance of the functions of the agency, including whether the information shall have practical utility; (b) the accuracy of the agency's estimate of the burden (including hours and cost) of the proposed collection of information; (c) ways to enhance the quality, utility, and clarity of the information to be collected; and (d) ways to minimize the burden of the collection of information on respondents, including through the use of automated collection techniques or other forms of information technology.

Comments submitted in response to this notice will be summarized and/or included in the request for OMB approval of this information collection; they also will become a matter of public record.

This public meeting is being held under the provisions of the Federal Advisory Committee Act of 1972 (5 U.S.C., Appendix, as amended), the Government in the Sunshine Act of 1976 (5 U.S.C. 552b, as amended), and 41 CFR 102-3.150.

Purpose of the Meeting: In Section 576(a)(2) of the National Defense Authorization Act for Fiscal Year 2013 (Pub. L. 112-239), as amended, Congress tasked the Judicial Proceedings Panel to conduct an independent review and assessment of judicial proceedings conducted under the Uniform Code of Military Justice (UCMJ) involving adult sexual assault and related offenses since the amendments made to the UCMJ by section 541 of the National Defense Authorization Act for Fiscal Year 2012 (Pub. L. 112-81; 125 Stat. 1404), for the purpose of developing recommendations for improvements to such proceedings. At this meeting, the Panel will deliberate on issues relating to restitution and compensation for sexual assault victims as well as retaliation against individuals who report incidents of sexual assault within the military. It will also examine military justice data for sexual assault crimes and comparative sentencing schemes. The Panel is interested in written and oral comments from the public, including non-governmental organizations, relevant to these issues or any of the Panel's tasks.

Availability of Materials for the Meeting: A copy of the October 9, 2015 public meeting agenda or any updates or changes to the agenda, to include individual speakers not identified at the time of this notice, as well as other materials provided to Panel members for use at the public meeting, may be obtained at the meeting or from the Panel's Web site at http://jpp.whs.mil.

Public's Accessibility to the Meeting: Pursuant to 5 U.S.C. 552b and 41 CFR 102-3.140 through 102-3.165, and the availability of space, this meeting is open to the public. Seating is limited and is on a first-come basis.

Special Accommodations: Individuals requiring special accommodations to access the public meeting should contact the Judicial Proceedings Panel at [email protected] at least five (5) business days prior to the meeting so that appropriate arrangements can be made.

Procedures for Providing Public Comments: Pursuant to 41 CFR 102-3.140 and section 10(a)(3) of the Federal Advisory Committee Act of 1972, the public or interested organizations may submit written comments to the Panel about its mission and topics pertaining to this public session. Written comments must be received by the JPP at least five (5) business days prior to the meeting date so that they may be made available to the Judicial Proceedings Panel for their consideration prior to the meeting. Written comments should be submitted via email to the Judicial Proceedings Panel at [email protected] in the following formats: Adobe Acrobat or Microsoft Word. Please note that since the Judicial Proceedings Panel operates under the provisions of the Federal Advisory Committee Act, as amended, all written comments will be treated as public documents and will be made available for public inspection. If members of the public are interested in making an oral statement, a written statement must be submitted along with a request to provide an oral statement. Oral presentations by members of the public will be permitted from 4:45 p.m. to 5:00 p.m. on October 9, 2015 in front of the Panel members. The number of oral presentations to be made will depend on the number of requests received from members of the public on a first-come basis. After reviewing the requests for oral presentation, the Chairperson and the Designated Federal Officer will, if they determine the statement to be relevant to the Panel's mission, allot five minutes to persons desiring to make an oral presentation.

Committee's Designated Federal Officer: The Panel's Designated Federal Officer is Ms. Maria Fried, Department of Defense, Office of the General Counsel, 1600 Defense Pentagon, Room 3B747, Washington, DC 20301-1600.

Background: Nine Federal agencies have been cooperating under a Memorandum of Understanding (MOU) on the research and development of multimedia environmental models. The MOU, which was revised in 2012, continues an effort that began in 2001. It establishes a framework for facilitating cooperation and coordination among the following agencies (the specific research organization within the agency is in parentheses): National Science Foundation; U.S. Army Corps of Engineers (Engineer Research and Development Center); U.S. Department of Agriculture (Natural Resources Conservation Service); U.S. Department of Energy (Office of Biological and Environmental Research); U.S. Environmental Protection Agency; U.S. Geological Survey; U.S. National Oceanographic and Atmosphere Administration; U.S. Nuclear Regulatory Commission (Office of Nuclear Regulatory Research); and U.S. Bureau of Reclamation. These agencies are cooperating and coordinating in the research and development (R&D) of multimedia environmental models, software and related databases, including development, enhancements, applications and assessments of site specific, generic, and process-oriented multimedia environmental models as they pertain to human and environmental health risk assessment. Multimedia model development and simulation supports interagency interests in risk assessment, uncertainty analyses, water supply issues and contaminant transport.

Purpose of the Public Meeting: The annual public meeting and workshop provides an opportunity for the scientific community, other Federal and State agencies, and the public to be briefed on ISCMEM activities and their initiatives for the upcoming year, and to discuss technological advancements in multimedia environmental modeling.

Proposed Agenda: The ISCMEM Chair will open the meeting with a brief overview of the goals of the MOU and an update on current activities of ISCMEM. This introduction will be followed by a series of invited presentations starting on Wednesday morning, October 28, 2015, and ending on Thursday afternoon, October 29, 2015.

Meeting Access: The meeting will be available through Web Meeting Services. To obtain web access to the ISCMEM October 28-29 meeting and workshop, all interested attendees will need to pre-register by emailing Julie Marcy ([email protected]) and Patrick Deliman ([email protected]), indicating their intent to participate in the meeting and providing their full contact information and affiliation.

On July 9, 2015, the DOE published a request for information in the Federal Register (80 FR 39422). DOE is seeking comments and information from interested parties to inform its policy development related to the possible establishment of a national reserve of power transformers that support the bulk power grid. The focus of the RFI is on the design and implementation of a National Power Transformer Reserve Program.

The July 9 notice requested comments and information from interested parties to inform its policy development related to the possible establishment of a national reserve of power transformers that support the bulk power grid by August 24, 2015. DOE is re-opening the comment period to allow additional time for more substantive comment on the significant questions to which DOE is seeking response.

DOE believes that re-opening the comment period to allow additional time for interested parties to submit comments is appropriate. Therefore, DOE is re-opening the comment period to provide interested parties additional time to prepare and submit comments and will consider any comments received by the new closing date. All comments received between the original August 24 closing date and the new closing date are considered timely filed, so people who submitted late comments during the original comment period do not need to re-submit comments.

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.

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.

Power from the Kerr-Philpott Projects is presently sold under 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. These rate schedules were approved by the FERC on March 11, 2011, for a period ending September 30, 2015 (134 FERC 62,233).

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.

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)).

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.

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.

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.

Availability:

This rate schedule shall be available to public bodies and cooperatives (any one of whom is hereinafter called the Customer) in Virginia and North Carolina to whom power may be transmitted and scheduled pursuant to contracts between the Government, Virginia Electric and Power Company (hereinafter called the Company), the Company's Transmission Operator, currently PJM Interconnection LLC (hereinafter called PJM), and the Customer. This rate schedule is applicable to customers receiving power from the Government on an arrangement where the Company schedules the power and provides the Customer a credit on their bill for Government power. Nothing in this rate schedule shall preclude modifications to the aforementioned contracts to allow an eligible customer to elect service under another rate schedule.

Applicability:

This rate schedule shall be applicable to the sale at wholesale of power and accompanying energy generated at the John H. Kerr and Philpott Projects and sold under appropriate contracts between the Government and the Customer.

Character of Service:

The electric capacity and energy supplied hereunder will be delivered at the delivery points of the Customer on the Company's transmission and distribution system.

Monthly Rate:

The initial base monthly rate for capacity, energy, and generation services provided under this rate schedule for the period specified shall be:

Initial Base Capacity Charge:

$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:

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 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.

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:

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 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.

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:

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 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.

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:

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.

Availability:

This rate schedule shall be available to public bodies and cooperatives (any one of whom is hereinafter called the Customer) in North Carolina and South Carolina to whom power may be transmitted and scheduled pursuant to contracts between the Government and Duke Energy Progress (formerly known as Carolina Power & Light Company and hereinafter called the Company) and the Customer. This rate schedule is applicable to customers receiving power from the Government on an arrangement where the Company schedules the power and provides the Customer a credit on their bill for Government power. Nothing in this rate schedule shall preclude modifications to the aforementioned contracts to allow an eligible customer to elect service under another rate schedule.

Applicability:

This rate schedule shall be applicable to the sale at wholesale of power and accompanying energy generated at the John H. Kerr and Philpott Projects and sold under appropriate contracts between the Government and the Customer.

Character of Service:

The electric capacity and energy supplied hereunder will be delivered at the delivery points of the Customer on the Company's transmission and distribution system.

Monthly Rate:

The initial base monthly rate for capacity, energy, and generation services provided under this rate schedule for the period specified shall be:

Initial Base Capacity Charge:

$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:

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.

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:

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.

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:

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 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.

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:

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 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.

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:

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 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.

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:

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 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.

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:

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.

Availability:

This rate schedule shall be available to public bodies and cooperatives (any one of whom is hereinafter called the Customer) in Virginia served through the facilities of American Electric Power Service Corporation (hereinafter called the Company) and PJM Interconnection LLC (hereinafter called PJM). The Customer has chosen to self-schedule and does not receive Government power under an arrangement where the Company schedules the power and provides a credit on the Customer's bill for Government power. The Customer is responsible for providing a scheduling arrangement with the Government and for providing a transmission arrangement. Nothing in this rate schedule shall preclude modifications to the aforementioned contracts to allow an eligible customer to elect service under another rate schedule.

Applicability:

This rate schedule shall be applicable to the sale at wholesale of power and accompanying energy generated at the John H. Kerr and Philpott Projects (hereinafter called the Projects) and sold under appropriate contracts between the Government and the Customer.

Character of Service:

The electric capacity and energy supplied hereunder will be delivered at the Projects.

Monthly Rate:

The initial base monthly rate for capacity, energy, and generation services provided under this rate schedule for the period specified shall be:

Initial Base Capacity Charge:

$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:

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 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.

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:

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 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.

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.

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.

Endangered Species Act [16 U.S.C. 1531 et al.]: EPA has analyzed the discharges proposed to be authorized by the General Permit, and their potential to adversely affect threatened or endangered species or their designated critical habitat areas in the vicinity of the discharges. Based on this analysis, EPA has determined that the issuance of this permit will have no effect to any threatened or endangered species in the vicinity of the discharge. Therefore, ESA consultation was not required.

National Environmental Policy Act (NEPA) [42 U.S.C. 4321 et.seq.] and Other Federal Requirements: Regulations at 40 CFR 122.49 list the federal laws that may apply to the issuance of permits i.e., ESA, National Historic Preservation Act, the Coastal Zone Act Reauthorization Amendments (CZARA), NEPA, and Executive Orders, among others. The NEPA compliance program requires analysis of information regarding potential impacts, development and analysis of options to avoid or minimize impacts, and development and analysis of measures to mitigate adverse impacts. EPA determined that no Environmental Assessments (EAs) or Environmental Impact Statements (EISs) are required under NEPA. EPA also determined that CZARA does not apply.

Essential Fish Habitat (EFH): The Magnuson-Stevens Fishery Management and Conservation Act requires EPA to consult with NOAA-NMFS when a proposed discharge has the potential to adversely affect a designated EFH. The EFH regulations define an adverse effect as “any impact which reduces quality and/or quantity of EFH . . . [and] may include direct (e.g. contamination or physical disruption), indirect (e.g. loss of prey, reduction in species' fecundity), site-specific or habitat-wide impacts, including individual, cumulative, or synergistic consequences of actions.” NMFS may recommend measures for attachment to the federal action to protect EFH; however, such recommendations are advisory, and not prescriptive in nature. EPA has evaluated the General Permit and has made the determination that issuance of the General Permit will have no effect on EFH.

Executive Order 12866: The Office of Management and Budget (OMB) exempts this action from the review requirements of Executive Order 12866 pursuant to Section 6 of that order.

Economic Impact [Executive Order 12291]: The EPA has reviewed the effect of Executive Order 12291 on this General Permit and has determined that it is not a major rule pursuant to that Order.

Paperwork Reduction Act [44 U.S.C. 3501 et seq. ]: The EPA has reviewed the requirements imposed on regulated facilities in the General Permit and finds them consistent with the Paperwork Reduction Act of 1980, 44 U.S.C. 3501 et seq.

Regulatory Flexibility Act [5 U.S.C. 601 et seq .]: The Regulatory Flexibility Act (RFA) requires that EPA prepare an initial regulatory flexibility analysis for rules subject to the requirements of the Administrative Procedures Act [APA, 5 U.S.C. 553] that have a significant impact on a substantial number of small entities. However, EPA has concluded that NPDES General Permits are not rulemakings under the APA, and thus not subject to APA rulemaking requirements or the RFA.

Section 201 of the Unfunded Mandates Reform Act (UMRA), Public Law 104-4, generally requires Federal agencies to assess the effects of their regulatory actions (defined to be the same as rules subject to the RFA) on tribal, state, and local governments, and the private sector. However, General NPDES Permits are not rules subject to the requirements of the APA, and are, therefore, not subject to the UMRA.

Any interested person may appeal the General Permit in the Federal Court of Appeals in accordance with section 509(b)(1) of the Clean Water Act, 33 U.S.C. 1369(b)(1). This appeal must be filed within 120 days of the General Permit issuance date. Affected persons may not challenge the conditions of the General Permit in further EPA proceedings (see 40 CFR 124.19). Instead, they may either challenge the General Permit in court or apply for an individual NPDES permit.

The Committee was established in December 2014 to make recommendations to the Commission on a wide array of disability matters within the jurisdiction of the Commission, and to facilitate the participation of people with disabilities in proceedings before the Commission. The Committee is organized under, and operated in accordance with, the provisions of the Federal Advisory Committee Act (FACA). The Committee held its first meeting on March 17, 2015.

At its October 8, 2015 meeting, the Committee will consider a recommendation from its Communications Subcommittee regarding ways to address the needs of people with disabilities in new and emerging technologies; will receive a report on the activities of its Emergency Communications Subcommittee; may consider proposed comments from its Relay/Equipment Distribution Subcommittee for the DAC to file in FCC Docket GN 13-5 regarding the transition of communication networks to Internet protocol; will receive a report on the activities of its Video Programming Subcommittee; and will consider recommendations from its Real Time Text (RTT) Ad Hoc Subcommittee regarding the FCC Public Notice about AT&T's Petition for Waiver and Petition for Rulemaking. The Committee will also celebrate the fifth anniversary of the Twenty-First Century Communications and Video Accessibility Act (CVAA), and may discuss new issues to be taken under consideration.

A limited amount of time may be available on the agenda for comments and inquiries from the public. The public may comment or ask questions of presenters via the email address [email protected].The meeting site is fully accessible to people using wheelchairs or other mobility aids. Sign language interpreters, open captioning, and assistive listening devices will be provided on site. Other reasonable accommodations for people with disabilities are available upon request. If making a request for an accommodation, please include a description of the accommodation you will need and tell us how to contact you if we need more information. Make your request as early as possible by sending an email to [email protected] or calling the Consumer and Governmental Affairs Bureau at 202-418-0530 (voice), 202-418-0432 (TTY). Last minute requests will be accepted, but may be impossible to fill. The meeting will be webcast with open captioning, at: www.fcc.gov/live.

To request materials in accessible formats for people with disabilities (Braille, large print, electronic files, audio format), send an email to [email protected] or call the Consumer and Governmental Affairs Bureau at (202) 418-0530 (voice), (202) 418-0432 (TTY).

The following information collection, which is being handled under this delegated authority, has received initial Board approval and is hereby published for comment. At the end of the comment period, the proposed information collection, along with an analysis of comments and recommendations received, will be submitted to the Board for final approval under OMB delegated authority. Comments are invited on the following:

a. Whether the proposed collection of information is necessary for the proper performance of the Federal Reserve's functions; including whether the information has practical utility;

b. The accuracy of the Federal Reserve's estimate of the burden of the proposed information collection, including the validity of the methodology and assumptions used;

c. Ways to enhance the quality, utility, and clarity of the information to be collected;

d. Ways to minimize the burden of information collection on respondents, including through the use of automated collection techniques or other forms of information technology; and

e. Estimates of capital or start up costs and costs of operation, maintenance, and purchase of services to provide information.

1. Report title: Requirements for Disclosure and Reporting of Community Reinvestment Act (CRA)-Related Agreements (Regulation G).

Agency form number: Reg G.

OMB control number: 7100-0299.

Frequency: On occasion and annual.

Reporters: State member banks and their subsidiaries; bank holding companies; savings and loan holding companies; and affiliates of bank holding companies and savings and loan holding institutions, other than banks, savings associations and subsidiaries of banks and savings associations; and nongovernmental entities or persons (NGEPs) that enter into covered agreements with any of the aforementioned companies.

Estimated annual reporting hours: Disclosure burden for insured depository institutions (IDI) and affiliates: Covered agreements to public, 6 hours; and Agreements relating to activities of CRA affiliates, 6 hours; Reporting burden for IDI and affiliates: Copy of agreements to agency, 8 hours; List of agreements to agency, 8 hours; Annual report, 8 hours; and Filing NGEP annual report, 6 hours; Disclosure burden for NGEP: Covered agreements to public, 6 hours; Reporting burden for NGEP: Copy of agreements to agency, 6 hours; and Annual report, 24 hours.

Estimated average hours per response: Disclosure burden for IDI and affiliates: Covered agreements to public, 1 hour; and Agreements relating to activities of CRA affiliates, 1 hour; Reporting burden for IDI and affiliates: Copy of agreements to agency, 1 hour; List of agreements to agency, 1 hour; Annual report, 4 hours; and Filing NGEP annual report, 1 hour; Disclosure burden for NGEP: Covered agreements to public, 1 hour; Reporting burden for NGEP: Copy of agreements to agency, 1 hour; and Annual report, 4 hours.

Number of respondents: Disclosure burden for IDI and affiliates: Covered agreements to public, 2 respondents; and Agreements relating to activities of CRA affiliates, 2 respondents; Reporting burden for IDI and affiliates: Copy of agreements to agency, 2 respondents; List of agreements to agency, 2 respondents; Annual report, 2 respondents; and Filing NGEP annual report, 2 respondents; Disclosure burden for NGEP: Covered agreements to public, 6 respondents; Reporting burden for NGEP: Copy of agreements to agency, 6 respondents; and Annual report, 6 respondents.

General description of report: This information collection is mandatory pursuant to Section 48 of the Federal Deposit Insurance Act (12 U.S.C. 1831y). The Board does not generally consider the information obtained under Regulation G to be confidential. However, a respondent may request confidential treatment under section (b)(4) of the Freedom of Information Act (FOIA). Section (b)(4) provides an exemption for “trade secrets and commercial or financial information obtained from a person and privileged or confidential” (5 U.S.C. 552(b)(4)). In order for a respondent to avail itself of this exemption, the respondent would have to show that the release of information would likely cause substantial harm to their competitive position. In addition, the information obtained under Regulation G may in appropriate circumstances also be withheld pursuant to section (b)(8) of the FOIA, which exempts information contained in “examination, operating, or condition reports prepared by, on behalf of, or for the use of an agency responsible for the regulation or supervision of financial institutions” (5 U.S.C. 552(b)(8)).

Abstract: Regulation G implements provisions of the Gramm-Leach-Bliley Act (GLBA) that require reporting and public disclosure of written agreements between (1) IDIs or their affiliates and (2) NGEPs, that are made in connection with the fulfillment of CRA requirements.1 The GLBA requires both IDIs and NGEPs to make a copy of any CRA-Related agreement available upon request and file an annual report with each relevant supervisory agency regarding the use of funds under such agreement for that fiscal year. In addition, an IDI and affiliate must provide to the relevant supervisory agency each calendar quarter a list of all CRA-related agreements entered into during the quarter with a copy of the agreement.

HHS announces OHS Tribal Consultations for leaders of Tribal Governments operating Head Start and Early Head Start programs. The agenda for the scheduled OHS Tribal Consultations in Anchorage, Alaska, and Choctaw, Mississippi, will be organized around the statutory purposes of Head Start Tribal Consultations related to meeting the needs of American Indian and Alaska Native children and families, taking into consideration funding allocations, distribution formulas, and other issues affecting the delivery of Head Start services in their geographic locations. In addition, OHS will share actions taken and in progress to address the issues and concerns raised in the 2014 OHS Tribal Consultations.

The Consultation Sessions will be conducted with elected or appointed leaders of Tribal Governments and their designated representatives [42 U.S.C. 9835, Section 640(l)(4)(A)]. Designees must have a letter from the Tribal Government authorizing them to represent the tribe. Tribal Governments must submit the designee letter at least 3 days in advance of the Consultation Session to Fran Majestic at [email protected]. Other representatives of tribal organizations and Native nonprofit organizations are welcome to attend as observers.

A detailed report of each Consultation Session will be prepared and made available within 45 days of the Consultation Sessions to all Tribal Governments receiving funds for Head Start and Early Head Start programs. Tribes wishing to submit written testimony for the report should send testimony to Fran Majestic at [email protected] either prior to each Consultation Session or within 30 days after each meeting. OHS will summarize oral testimony and comments from the Consultation Session in each report without attribution, along with topics of concern and recommendations.

Federal awardee of record and intended award amount is:

Amount of the Award(s): Up to $330,000.

CFDA Number: 93.117.

Current Project Period: September 1, 2014, through August 31, 2017.

Period of Supplemental Funding: September 1, 2014, through August 31, 2017.

Authority: Section 765 of the Public Health Service Act (42 U.S.C. 295 and 295a), as amended by Section 5206 of the Patient Protection and Affordable Care Act.

HRSA seeks to provide a program expansion supplement of $330,000 for the Center for Integrative Medicine in Primary Care Program award for the purpose of increasing the number of pilot sites and disciplines that are reached with the initial offering of the Foundations in Integrative Healthcare online course. The program will be able to accomplish outreach to a broad range of disciplines, health professionals, types of programs, and underrepresented groups. They also will be able to provide outreach to consumers on integrative healthcare. This request is for a single-award deviation because there is only one currently funded cooperative agreement with the capacity to use the funding during the required time period.