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in kilowatts. The control area service charge would be 50 percent of the costs incurred under the Oversupply Management Protocol multiplied by the nameplate capacity of each participating generator, divided by the sum of all generating facility nameplate capacities of all participating generators.

BPA proposes to bill for costs incurred prior to the effective date of the
OS–14 rate after the effective date of the OS–14 rate. BPA would include charges
for costs incurred after the effective date
on the bill for the month those costs were incurred, subject to a rate cap as discussed below. BPA proposes to make
the OS–14 rates effective until all costs
have been billed and such bills have been fully paid.

BPA is proposing to cap the total
amount that would be billed under each Oversupply rate at $4,000,000 in any one month. The rate cap would allow the billing to be spread over several
months to ease the cash flow effect on customers. Any oversupply costs in excess of the cap will carry over to subsequent months’ bills until the balance is completely billed.

Part V—Proposed Oversupply Rate
Schedules

BPA’s proposed 2014 control area service Oversupply Rate Schedule and power General Rate Schedule Provision Oversupply Rate are a part of this notice and are available for viewing and downloading on BPA’s Web site at www.bpa.gov/goto/OS14Schedule Copies of the proposed rate schedules also are available for viewing in BPA’s
Public Reference Room at the BPA Headquarters, 1st Floor, 905 NE 11th Avenue, Portland, OR 97232.

Issued this 29th day of October, 2012. Stephen J. Wright, Administrator and Chief Executive Officer.

[FR Doc. 2012–27306 Filed 11–7–12; 8:45 am]

**BILLING CODE 6450–01–P**

**DEPARTMENT OF ENERGY**

**Bonneville Power Administration**

**[BPA File No. BP–14]**

**Fiscal Year (FY) 2014–2015 Proposed**
**Power and Transmission Rate Adjustments; Public Hearing and**  **Opportunities for Public Review and**
**Comment**

**AGENCY :**  Bonneville Power Administration (BPA or Bonneville), Department of Energy (DOE).

**ACTIONS :**  Notice of FY 2014–2015 Proposed Power and Transmission Rate Adjustments. **SUMMARY :**  BPA is holding a consolidated rate proceeding, Docket No. BP–14, to establish power and transmission rates
for FY 2014–2015.

The Pacific Northwest Electric Power Planning and Conservation Act (Northwest Power Act) provides that BPA must establish and periodically review and revise its rates so that they recover, in accordance with sound business principles, the costs associated with the acquisition, conservation, and transmission of electric power, including amortization of the Federal
investment in the Federal Columbia River Power System (FCRPS) over a reasonable number of years and BPA’s other costs and expenses. The Northwest Power Act also requires that
BPA’s rates be established based on the record of a formal hearing, and for transmission rates only, that the costs of the Federal transmission system be equitably allocated between Federal and non-Federal power utilizing the system. By this notice, BPA announces the commencement of a power and transmission rate adjustment proceeding for power, transmission, control area services, and ancillary services rates proposed to be effective on October 1,

2013.

**DATES :**  Anyone wishing to become a party to the BP–14 proceeding must provide written notice, via U.S. Mail or electronic mail, which must be received by BPA no later than 3:00 p.m. on November 15, 2012.

The BP–14 rate adjustment proceeding begins with a prehearing conference at 9:00 a.m. on November 14, 2012, in the BPA Rates Hearing Room, 2nd floor, 911 NE 11th Avenue, Portland, Oregon 97232.

Written comments by non-party participants must be received by February 15, 2013, to be considered in
the Administrator’s Record of Decision (ROD).

**ADDRESSES :** 

1. Petitions to intervene should be directed to: Hearing Clerk—L–7, Bonneville Power Administration, 905 NE 11th Avenue, Portland, Oregon 97232, or may be emailed to rateclerk@bpa.gov. In addition, copies of the petition must be served concurrently on BPA’s General Counsel and directed to both Mr. Peter J. Burger, LP–7, and Mr. Barry Bennett, LC–7, Office of General Counsel, 905 NE 11th Avenue, Portland, Oregon 97232, or via
email to pjburger@bpa.gov and bbennett@bpa.gov (see section III.A. for more information regarding interventions).

2. Written comments by participants
should be submitted to the Public Engagement Office, DKE–7, Bonneville Power Administration, P.O. Box 14428, Portland, Oregon 97293. Participants may also submit comments by email at: www.bpa.gov/comment. BPA requests that all comments and documents intended to be part of the Official Record in this rate proceeding contain the designation BP–14 in the subject
line.

**FOR FURTHER INFORMATION CONTACT :**  Ms. Heidi Y. Helwig, DKC–7, Public Affairs Specialist, Bonneville Power Administration, P.O. Box 3621, Portland, Oregon 97208; by phone toll free at 1–800–622–4520; or via email to hyhelwig@bpa.gov.

Responsible Officials: Mr. Raymond D. Bliven, Power Rates Manager, is the official responsible for the development of BPA’s power rates, and Ms. Rebecca E. Fredrickson, Transmission Rates Manager, is the official responsible for the development of BPA’s transmission, ancillary and control area services (ACS) rates.

**SUPPLEMENTARY INFORMATION :** 

Table of Contents

Part I. Introduction and Procedural Background Part II. Scope of 2014 Rate Proceeding Part III. Public Participation in BP–14 Part IV. Summary of Rate Proposals Part V. Proposed 2014 Rate Schedules

Part I—Introduction and Procedural Background

Section 7(i) of the Northwest Power Act, 16 U.S.C. 839e(i), requires that BPA’s rates be established according to certain procedures, including publication in the Federal Register of this notice of the proposed rates; one or more hearings conducted as expeditiously as practicable by a Hearing Officer; opportunity for both oral presentation and written submission of views, data, questions, and arguments related to the proposed rates; and a decision by the
Administrator based on the record. BPA’s rate proceedings are further governed by BPA’s Procedures Governing Bonneville Power Administration Rate Hearings, 51 Federal Register 7611 (1986), which implement and expand the statutory requirements.

This proceeding is being conducted under the rule for general rate proceedings, section 1010.4 of BPA’s Procedures. A proposed schedule for the proceeding is provided below. A final schedule will be established by the Hearing Officer at the prehearing
conference.

BPA Direct Case November 14, 2012


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Prehearing Conference November 14, 2012
Parties File Petition to Intervene November

15, 2012 Clarification November 27–30, 2012 Motions to Strike December 7, 2012 Data Request Deadline December 7, 2012 Answers to Motions to Strike December 14,

2012 Data Response Deadline December 14, 2012 Parties file Direct Case January 18, 2013 Clarification January 29–February 1, 2013 Motions to Strike February 6, 2013 Data Request Deadline February 6, 2013 Answers to Motions to Strike February 13,

2013 Data Response Deadline February 13, 2013 Close of Participant Comments February 15,

2013 Litigants file Rebuttal March 5, 2013 Clarification March 7–8, 2013 Motions to Strike March 13, 2013 Data Request Deadline March 13, 2013 Answers to Motions to Strike March 20,

2013 Data Response Deadline March 20, 2013 Cross-Examination March 25–29, 2013 Initial Briefs Filed April 29, 2013 Oral Argument May 9, 2013 Draft ROD issued June 11, 2013 Briefs on Exceptions June 28, 2013 Final ROD—Final Studies July 22, 2013

Section 1010.7 of BPA’s Procedures prohibits ex parte communications. The ex parte rule applies to all BPA and DOE employees and contractors. Except as provided below, any outside
communications with BPA and/or DOE personnel regarding the merits of any issue in BPA’s rate proceeding by other Executive Branch agencies, Congress, existing or potential BPA customers (including tribes), or nonprofit or public interest groups are considered outside communications and are subject to the ex parte rule. The rule does not apply to communications relating to: (1) Matters of procedure only (the status of the rate proceeding, for example); (2) exchanges of data in the course of
business or under the Freedom of Information Act; (3) requests for factual information; (4) matters for which BPA is responsible under statutes other than the ratemaking provisions; or (5) matters which all parties agree may be made on

an ex parte basis. The ex parte rule
remains in effect until the Administrator’s Final ROD is issued,
which is scheduled to occur on or about July 22, 2013.

Part II—Scope of 2014 Rate Proceeding

A. Joint Rate Proceeding

BPA is holding one power and transmission rate proceeding with one procedural schedule, one record, and

one ROD.

B. 2012 Integrated Program Review

BPA began its 2012 Integrated Program Review (IPR) process in June 2012. The IPR process is designed to allow persons interested in BPA’s program levels an opportunity to review and comment on BPA’s expense and capital spending level estimates prior to the use of those estimates in setting

rates.

The 2012 IPR focused on FY 2014 and FY 2015 program levels for BPA’s Power
Services and Transmission Services as well as a review of FY 2013 program levels. After the opening workshop on June 5 and release of information, participants were allowed three weeks to request specific workshops. Participants requested additional information through the end of July 2012. BPA responded to participants’ requests for additional information and held two days of technical workshops through July 18, 2012. BPA took public comment through August 10, 2012.

Between March and April 2012, prior to the initiation of the IPR, BPA hosted the 2012 Capital Investment Review (CIR), a new public process focused on reviewing and discussing draft asset strategies and 10-year capital forecasts. Public comments received during the CIR informed capital cost projections for
FY 2014–2015 in the 2012 IPR.

On October 26, 2012, BPA issued the Final Close-Out Report for the IPR. In the Final Close-Out Report, BPA established the program level cost
estimates that are used in the Initial Proposal to establish both the power
and transmission rates. BPA does not anticipate additional public review of proposed spending levels. However, BPA is open to revisiting spending levels in an ‘‘IPR–2’’ process if
conditions in FY 2013 warrant it. BPA would conduct this process separately from the rate proceeding to share updates and solicit feedback from
customers and constituents before the final program levels are incorporated
into the final rates.

C. Rate Case Workshops

In preparation for the BP–14 rate proceeding, BPA held several public pre-rate case workshops with customers and interested parties from March through early October 2012. During the workshops, BPA staff presented and discussed information about costs, load and resource forecasting, generation inputs pricing, segmentation, cost allocation, redispatch, utility delivery, Montana Intertie, revenue forecasts, load forecasts, risk analysis and mitigation, products, pricing, and rate design. Customers and interested parties had extensive opportunity to participate, raise issues, present alternative proposals, and comment on the information BPA staff presented. The comments and alternative proposals received during these workshops have assisted in the preparation of the Initial Proposal.

D. Scope of the Rate Proceeding

This section provides guidance to the Hearing Officer as to those matters that are within the scope of the rate proceeding and those that are outside the scope.

1. Program Cost Estimates

Some of the decisions that determine program costs and spending levels have been made in the IPR public review process outside the rate proceeding. See section II.B. BPA’s spending levels for investments and expenses are not determined or subject to review in rate proceedings.

Pursuant to section 1010.3(f) of BPA’s Procedures, the Administrator directs the Hearing Officer to exclude from the record all argument, testimony, or other evidence that challenges the appropriateness or reasonableness of the
Administrator’s decisions on cost and spending levels. If, and to the extent that, any re-examination of spending levels is necessary, such re-examination
will occur outside of the rate proceeding. This exclusion does not extend to those portions of the revenue requirements related to interest rate forecasts, interest expense and credit, Treasury repayment schedules, forecasts of depreciation and amortization expense, forecasts of system replacements used in repayment studies, Residential Exchange Program benefits, purchased power expenses, transmission acquisition expense incurred by Power Services, generation acquisition expense incurred by Transmission Services, minimum required net revenue, and the costs of risk mitigation actions resulting from the expense and revenue uncertainties included in the risk analysis. The Administrator also directs the Hearing Officer to exclude argument and evidence regarding BPA’s debt management practices and policies. See

section II.D.5.

2. Tiered Rate Methodology (TRM)

The TRM restricts BPA and customers with Contract High Water Mark (CHWM) contracts from proposing changes to the TRM’s ratesetting guidelines unless certain procedures have been successfully concluded. No proposed changes have been subjected to the required procedures.

Pursuant to § 1010.3(f) of BPA’s Procedures, the Administrator hereby directs the Hearing Officer to exclude from the record all argument, testimony,


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or other evidence that seeks in any way to propose revisions to the TRM made by BPA, customers with a CHWM contract, or their representatives, unless
it can be established that the TRM procedures for proposing a change to
the TRM have been concluded. This restriction does not extend to a party or
customer that does not have a CHWM

contract.

3. Service to the Direct Service Industries (DSIs)

The manner and method by which BPA provides service to its DSI customers was recently addressed in the
Alcoa v. Bonneville Power
Administration decision,

___ F3d

___, 2012 WL 4873329, which reflected the Courts’ prior decisions in Pacific Northwest Generating Cooperative, et al., v. Bonneville Power Administration, 580 F3d 792 (9th Cir. 2008) (PNGC I)
and Pacific Northwest Generating Cooperative, et al., v. Bonneville Power Administration, 590 F3d 1065 (9th Cir. 2010) (PNGC II). BPA is assuming for the Initial Proposal that BPA will continue to serve Alcoa, Inc. (Alcoa) as well as Port Townsend Paper Corporation (Port Townsend) during FY
2014–2015. BPA’s decisions to serve Alcoa, along with the method and level of service to be provided DSIs in the FY 2014–2015 rate period, will not be determined in this proceeding but
instead will be made and documented in a Record of Decision following a currently open public comment period on a proposed ten year power sales
contract with Alcoa.

Pursuant to § 1010.3(f) of BPA’s Procedures, the Administrator directs the Hearing Officer to exclude from the record all argument, testimony, or other evidence that seeks in any way to revisit the appropriateness or reasonableness of BPA’s decisions regarding service to the DSIs, including BPA’s decision to offer
contracts to the DSIs and the method or
level of service.

4. Generation Inputs

BPA provides a portion of the available generation from the FCRPS to
enable Transmission Services to meet its various requirements. Transmission Services uses these generation inputs to provide ancillary and control area
services. To recover the costs associated with providing generation inputs, BPA determines prices for the generation inputs that become the basis of the reserves-based ancillary and control
area services. The forecast amount of generation inputs, the pricing methodologies BPA is proposing to use to determine the generation input costs, and associated proposed Ancillary and Control Area Service rates are matters that are included within the scope of the BP–14 proceeding.

Pursuant to § 1010.3(f) of BPA’s Procedures, the Administrator directs the Hearing Officer to exclude from the record all argument, testimony, or other evidence that seeks in any way to revisit the appropriateness or reasonableness of any other issues related to the generation inputs or Ancillary and
Control Area Services. This exclusion includes, but is not limited to, issues regarding reliability of the transmissionsystem, dispatcher standing orders, eTag requirements and definitions, open acess transmission tariff provisions, and business practices. These non-rates issues are generally addressed by BPA in accordance with industry, reliability, and other compliance standards and criteria and are not matters appropriate for the rate proceeding.

5. Federal and Non-Federal Debt Service and Debt Management

During the 2012 IPR and in other forums, BPA provided the public with background information on BPA’s
internal Federal and non-Federal debt management policies and practices. While these policies and practices are not decided in the IPR forum, these
discussions were intended to inform interested parties about these matters so that they would better understand
BPA’s debt structure. BPA’s debt management policies and practices remain outside the scope of the rate proceeding.

Pursuant to § 1010.3(f) of BPA’s Procedures, the Administrator hereby directs the Hearing Officer to exclude from the record all argument, testimony, or other evidence that seeks in any way to address the appropriateness or
reasonableness of BPA’s debt management policies and practices. This exclusion does not encompass how debt management actions are reflected in ratemaking.

6. Potential Environmental Impacts

Environmental impacts are addressed
in a concurrent National Environmental Policy Act (NEPA) process. See section

II.E.

Pursuant to § 1010.3(f) of BPA’s Procedures, the Administrator directs the Hearing Officer to exclude from the record all argument, testimony, or other evidence that seeks in any way to address the potential environmental impacts of the rates being developed in this rate proceeding. 7. Average System Cost Methodology and Average System Cost

Determinations

Section 5(c) of the Northwest Power
Act established the Residential Exchange Program, which provides
benefits to residential and small-farm
consumers of Pacific Northwest utilities based, in part, on a utility’s ‘‘average system cost’’ (ASC) of resources. Section 5(c)(7) of the Act requires the Administrator to consult with regional interests to develop an ASC Methodology (ASCM), which prescribes the methodology that the Administrator uses to calculate a utility’s ASC. On September 4, 2009, the Federal Energy Regulatory Commission (Commission) granted final approval of BPA’s 2008 ASCM. The 2008 ASCM is not subject to challenge or review in a section 7(i) proceeding. Determinations of the ASCs of participating utilities are made in separate processes conducted pursuant to the ASCM. Those processes began with ASC filings on June 1, 2012, and are continuing through July 2013. The determinations of ASCs are not subject to challenge or review in a section 7(i) proceeding.

Pursuant to § 1010.3(f) of BPA’s Procedures, the Administrator hereby directs the Hearing Officer to exclude from the record all argument, testimony, or other evidence that seeks in any way to visit or revisit the appropriateness or
reasonableness of the 2008 ASCM. The Administrator also directs the Hearing
Officer to exclude from the record all argument, testimony, or other evidence that seeks in any way to visit or revisit the appropriateness or reasonableness of any of the ongoing ASC determinations.

8. Rate Period High Water Mark (RHWM) Process

Under the Tiered Rate Methodology (TRM), BPA has established FY 2014–
2015 RHWMs for Public customers that signed contracts for firm requirements power service providing for tiered rates,
referred to as CHWM contracts. In this RHWM Process, which preceded the BP–14 rate proceeding, BPA established the maximum planned amount of power a customer is eligible to purchase at Tier 1 rates during the rate period, the Above-RHWM Loads for each customer, the System Shaped Load for each customer, the Tier 1 System Firm Critical Output, RHWM Augmentation, the Rate Period Tier 1 System Capability (RT1SC), and the monthly/diurnal shape of RT1SC. The RHWM Process provided customers an opportunity to review, comment, and, if necessary, challenge BPA’s determinations


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regarding certain RHWM
determinations.

Pursuant to § 1010.3(f) of BPA’s Procedures, the Administrator hereby directs the Hearing Officer to exclude from the record all argument, testimony, or other evidence that seeks in any way
to visit or revisit BPA’s determination of

a customer’s FY 2014–2015 RHWM or
other RHWM Process determinations.

9. 2012 Residential Exchange Program Settlement Agreement (2012 REP Settlement)

On July 26, 2011, the Administrator
executed the 2012 REP Settlement with
over one hundred customers and other regional parties resolving longstanding litigation over BPA’s implementation of the Residential Exchange Program (REP) under section 5(c) of the Northwest Power Act, 16 U.S.C. 839c(c). Parties were afforded an opportunity to challenge the legal, factual, and policy
merits of the 2012 REP Settlement in the REP–12 administrative hearing, an eight-month administrative proceeding conducted under the procedural rules of section 7(i) of the Northwest Power Act, 16 U.S.C. 839e(i). The Administrator’s findings regarding the legal, factual, and policy challenges to the 2012 REP Settlement are thoroughly explained in the 419-page REP–12 Record of Decision (REP–12 ROD). The 2012 REP
Settlement and REP–12 ROD are currently under review before the U.S. Court of Appeals for the Ninth Circuit (Ninth Circuit).

Because BPA’s decision to adopt the 2012 REP Settlement was made as part of the REP–12 ROD, which is already under review by the Court, challenges to BPA’s decision to adopt the 2012 REP Settlement and implement its terms in BPA’s rate proceedings are not within the scope of this case. Pursuant to § 1010.3(f) of BPA’s Procedures, the Administrator hereby directs the Hearing Officer to exclude from the record all argument, testimony, or other evidence that seeks in any way to visit or revisit BPA’s determination to adopt the 2012 REP Settlement or implement its terms in this rate proceeding.

Although challenges to BPA’s decision to adopt the 2012 REP Settlement and implement its terms in BPA’s rate proceedings are not within the scope of this case, the Hearing Officer shall permit BPA and the rate case parties, through a ‘‘standstill’’ agreement, to incorporate by reference material from the BP–12 proceeding,
which includes the record from the REP–12 proceeding. E. The National Environmental Policy Act (NEPA)

BPA is in the process of assessing the potential environmental effects of its proposed power and transmission rates,
consistent with NEPA. The NEPA process is conducted separately from the rate proceeding. As discussed in section II.D.6., all evidence and argument addressing potential environmental impacts of rates being developed in the BP–14 rate proceeding are excluded from the rate proceeding hearing record. Instead, comments on
environmental effects should be directed to the NEPA process.

Because this proposal involves BPA’s ongoing business practices related to rates, BPA is reviewing the proposal for consistency with BPA’s Business Plan Environmental Impact Statement (Business Plan EIS), completed in June 1995 (BOE/EIS–0183). This policy-level
EIS evaluates the environmental impacts of a range of business plan
alternatives for BPA that could be varied by applying various policy modules, including one for rates. Any combination of alternative policy
modules should allow BPA to balance
its costs and revenues. The Business Plan EIS also includes response strategies, such as adjustments to rates, that BPA could implement if BPA’s
costs exceed its revenues.

In August 1995, the BPA Administrator issued a ROD (BusinessPlan ROD) that adopted the MarketDriven Alternative from the Business
Plan EIS. This alternative was selected because, among other reasons, it allows BPA to: (1) Recover costs through rates; (2) competitively market BPA’s products and services; (3) develop rates that meet customer needs for clarity and simplicity; (4) continue to meet BPA’s legal mandates; and (5) avoid adverse environmental impacts. BPA also committed to apply as many response strategies as necessary when BPA’s costs
and revenues do not balance.

In April 2007, BPA completed and issued a Supplement Analysis to the Business Plan EIS. This Supplement Analysis found that the Business PlanEIS’s relationship-based and policylevel analysis of potential environmental impacts from BPA’s business practices remains valid, and that BPA’s current business practices
remain consistent with BPA’s MarketDriven Alternative approach. The
Business Plan EIS and ROD thus continue to provide a sound basis for making determinations under NEPA concerning BPA’s policy-level decisions, including rates. Because the proposed rates likely would assist BPA in accomplishing the goals identified in the Business Plan ROD, the proposal appears consistent with these aspects of the Market-Driven Alternative. In addition, this rate proposal is similar to the type of rate designs evaluated in the Business Plan EIS; thus, implementation of this rate proposal would not be expected to result in environmental impacts significantly different from those
examined in the Business Plan EIS. Therefore, BPA expects that this rate proposal will likely fall within the scope of the Market-Driven Alternative
that was evaluated in the Business Plan EIS and adopted in the Business Plan

ROD.

As part of the Administrator’s ROD that will be prepared for the BP–14 rate proceeding, BPA may tier its decision
under NEPA to the Business Plan ROD. However, depending upon the ongoing environmental review, BPA may instead issue another appropriate NEPA document. Comments regarding the potential environmental effects of the proposal may be submitted to Katherine Pierce, NEPA Compliance Officer, KEC– 4, Bonneville Power Administration, 905 NE 11th Avenue, Portland, OR 97232. Any such comments received by the comment deadline for Participant
Comments identified in section III.A. below will be considered by BPA’s NEPA compliance staff in the NEPA process that will be conducted for this proposal.

Part III—Public Participation in BP–14

A. Distinguishing Between ‘‘Participants’’ and ‘‘Parties’’

BPA distinguishes between ‘‘participants in’’ and ‘‘parties to’’ the hearings. Apart from the formal hearing process, BPA will receive written comments, views, opinions, and information from ‘‘participants,’’ who may submit comments without being subject to the duties of, or having the privileges of, parties. Participants’ written comments will be made part of the official record and considered by the Administrator. Participants are not entitled to participate in the prehearing conference; may not cross-examine parties’ witnesses, seek discovery, or serve or be served with documents; and are not subject to the same procedural requirements as parties. BPA customers whose rates are subject to this proceeding, or their affiliated customer groups, may not submit participant comments. Members or employees of organizations that have intervened in the rate proceeding may submit general comments as participants but may not


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use the comment procedures to address specific issues raised by their intervenor organizations.

Written comments by participants will be included in the record if they are received by February 15, 2013. Written views, supporting information, questions, and arguments should be
submitted to the address listed in the

**ADDRESSES** section of this notice.

Entities or persons become parties to the proceeding by filing petitions to intervene, which must state the name and address of the entity or person requesting party status and the entity’s or person’s interest in the hearing. BPA
customers and affiliated customer groups will be granted intervention based on petitions filed in conformance
with BPA’s Procedures. Other petitioners must explain their interests in sufficient detail to permit the Hearing
Officer to determine whether the petitioners have a relevant interest in the hearing. Pursuant to Rule 1010.1(d) of BPA’s Procedures, BPA waives the requirement in Rule 1010.4(d) that an opposition to an intervention petition be
filed and served 24 hours before the prehearing conference. The time limit for opposing a timely intervention will be established at the prehearing conference. Any party, including BPA, may oppose a petition for intervention. All petitions will be ruled on by the Hearing Officer. Late interventions are strongly disfavored. Opposition to an untimely petition to intervene must be filed and received by BPA within two days after service of the petition. BPA is holding the OS–14 Oversupply rate proceeding at the same time as the BP– 14 rate proceeding. However, these proceedings are separate. As a result, entities or persons wishing to intervene in both dockets must file a separate petition to intervene in each rate proceeding, and all filings must be made in the rate proceeding to which the filing pertains.

B. Developing the Record

The hearing record will include, among other things, the transcripts of the hearing, written evidence and argument entered into the record by BPA and the parties, written comments from participants, and other material accepted into the record by the Hearing Officer. The Hearing Officer will review the record and certify the record to the
Administrator for final decision.

The Administrator will develop final
rates based on the record and such other materials and information as may have been submitted to or developed by the
Administrator. The Administrator will serve copies of the Final ROD on all parties. BPA will file its rates with the Commission for confirmation and approval after issuance of the Final

ROD.

Part IV—Summary of Rate Proposals

A. Summary of the Power Rate Proposal

1. Power Rates

BPA is proposing five different rates for Federal power sales and services. In 2012, BPA signed the 2012 REP
Settlement. See section II.D.9. Ratesetting in this proceeding implements the Settlement according to

its terms.

Priority Firm Power Rate (PF–14)— The PF rate schedule applies to net requirements power sales to public body, cooperative, and Federal agency customers made pursuant to section 5(b)
of the Northwest Power Act and
includes the PF Public rates for the sale of firm requirements power under CHWM Contracts and the PF Exchange
rates for sales under Residential Purchase and Sale Agreements. The PF Public rate applies to customers taking load following or Slice/block service. Consistent with the TRM, Tier 1 rates include three charges: (1) Customer charges; (2) a demand charge; and (3) a load shaping charge. In addition, three Tier 2 rates, corresponding to contract options, are provided for customers that have chosen to purchase power from BPA for service to their load above high
water mark.

About 75 percent of BPA’s power revenues are paid under the PF rate schedule and 95 percent of the power revenues under rates adjusted in this proceeding (PF, IP, NR and FPS). Therefore, BPA expresses its overall rate increase in terms measured by the increase in the PF rate. However, the PF rate is a collection of rates charged on the basis of percentage of cost responsibility, marginal changes in demand and energy usage, purchase elections for loads in excess of power purchased at Tier 1 rates, product and service choices, and applicability of rate discounts. Very few of BPA’s customers have exactly the same mix of PF rate components in common. Therefore, BPA has developed a quantification of the PF rate that measures the impact on an average customer purchasing at Tier 1 rates. This quantification, the Tier 1 Average Net Cost, is increasing 9.6 percent in this proposal. Individual customer impacts vary around this increase, but most PF customers will experience a lower increase in its power bills, and customers that purchase the Slice product will experience a large portion of this increase through the lower value of Slice surplus power rather than through their BPA power bills. Altogether, BPA expects that this rate proposal will increase its revenues by $158 million per year, an 8 percent
increase over revenues if rates did not change.

The Base PF Exchange rate and its associated surcharges apply to the sale of power to regional utilities that participate in the REP established under section 5(c) of the Northwest Power Act. 16 U.S.C. 839c(c). The Base PF Exchange rate establishes the threshold for participation in the REP; only
utilities with ASCs above the appropriate Base PF Exchange rate may receive REP benefits. If a utility meets the threshold, a utility-specific PF Exchange rate will be established in this proceeding for each eligible utility. The utility-specific PF Exchange rate is used in calculating the REP benefits each participant will receive during FY

2014–2015.

In addition, the proposed PF–14 rate
schedule includes rates for customers
with non-Federal resources that have elected to take Diurnal Flattening Service or Secondary Crediting Service, and a melded PF rate for any Public customers that elects a power sales
contract other than a CHWM Contract for firm requirements service.

New Resource Firm Power Rate (NR– 14)—The NR–14 rate applies to netrequirements power sales to investorowned utilities (IOUs) made pursuant to section 5(b) of the Northwest Power Act for resale to ultimate consumers, direct consumption, construction, testing and start-up, and station service. The NR–14 rate is also applied to sales of firm power to Public customers serving new large single loads. In the Initial Proposal BPA is forecasting no sales at the NR rate. The average NR–14 rate in the Initial Proposal is $73.63/MWh, an increase of 5.9 percent from the NR–12

rate.

Industrial Firm Power Rate (IP–14)— The IP rate is applicable to firm power sales to DSI customers authorized by section (5)(d)(1)(A) of the Northwest Power Act. 16 U.S.C. 839c(d)(1)(A). In the Initial Proposal BPA is forecasting annual sales of 312 average megawatts (aMW) to DSIs. See section IV.A.2c. The average IP–14 rate in the Initial Proposal is $38.98/MWh, an increase of 7.4 percent over the IP–12 rate.

Firm Power Products and Services Rate (FPS–14)—The FPS rate schedule is applicable to purchasers of Firm Power, Capacity Without Energy, Supplemental Control Area Services, Shaping Services, Reservation and Rights to Change Services, and Reassignment or Remarketing of Surplus Transmission Capacity, for use inside
and outside the Pacific Northwest. The


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rates for these products are negotiated between BPA and the purchaser. In addition, the FPS–14 rate schedule
includes rates for customers with nonFederal resources that have elected to take Resource Support Services, Resource Shaping Services, or Transmission Scheduling Service/ Transmission Curtailment Management Service and Forced Outage Reserve

Service.

General Transfer Agreement Service Rate (GTA–14)—The GTA rate schedule includes the GTA Delivery Charge and Transfer Service Operating Reserve Charge. The GTA Delivery Charge applies to customers that purchase Federal power that is delivered over non-Federal low-voltage transmission facilities. BPA is proposing to change the basis for determining the GTA Delivery Charge. The proposed rate isbased on the cost of low-voltage nonFederal delivery service provided by third-party transmission providers. In addition, the proposed billing determinant uses the customer system peak. BPA is also proposing to continue an Operating Reserves rate for transfer
service customers that will become effective when proposed changes to Western Electricity Coordinating Council (WECC) Operating Reserve Requirements become effective.

2. Important Features of the BP–14 Initial Rate Proposal for Power Rates and Ancillary Service and Control Area

Service Rates

a. Tiered PF Rate

No significant changes are proposed
for the tiered PF rate. Several minor changes are proposed to address issues that have arisen during the first year of application of the tiered rate design, including modifications to the demand rate billing determinants and to certain aspects of Tier 2 rates, and wording corrections to some power rate schedules.

b. Generation Inputs; Ancillary and
Control Area Services

For FY 2014–2015, BPA expects to purchase balancing reserve capacity from non-Federal sources to provide balancing services within its balancing authority area. BPA is proposing a methodology to assign the costs of Federal balancing reserve capacity and non-Federal balancing reserve capacity.

VERBS provides the generation capability (ability to both increase anddecrease generation) to follow withinhour variations of variable energy resources in the BPA Balancing Authority Area. The proposed methodology for calculating the Variable Energy Resource Balancing
Service rate for service from Federal
resources is similar to the BP–12 methodology. However, BPA is proposing to make several changes to its rate options under VERBS. The proposed VERBS rate recovers the cost of regulating reserves, following reserves, and imbalance reserves that are necessary to balance the within-hour schedule deviations of variable energy resources. The proposed VERBS rate will also recover certain directly assigned costs that are associated with providing VERBS.

The proposed VERBS rate is comprised of a base rate and four formula rate adjustments, which are designed to recover the costs associated with: (1) The purchase of non-Federal balancing reserve capacity on a planning basis to provide VERBS; (2) replacing, if necessary, FCRPS balancing reserve capacity that becomes unavailable during the rate period with reserve acquisitions from non-Federal sources in order to continue providing VERBS and Dispatchable Energy Resource Balancing Service (DERBS) forthe rate period; (3) purchases of nonFederal balancing reserve capacity to support a ‘‘Full Service’’ VERBS option for customers that elect this service; and (4) acquisitions of non-Federal balancing reserve capacity to support an unplanned increase in balancing services. BPA is also proposing to provide a rate credit to VERBS
customers for embedded and variable costs associated with FCRPS balancing reserve capacity that becomes unavailable during the rate period because of hydro-related conditions.

BPA is proposing to provide a
discounted base rate to VERBS customers that participate in ‘‘committed intra-hour scheduling,’’ in which customers agree to schedule on a half-hour basis in every schedule interval at a specific level of scheduling

accuracy.

BPA is proposing to discontinue Provisional Variable Energy Resource Balancing Service (also known as ‘‘Provisional Balancing Service’’) and its
associated rate.

DERBS is necessary to support the
within-hour deviations of thermal generation from the hourly generation estimate (i.e., schedule). BPA proposes
to base its calculation of the DERBS rate on 5-minute average revenue meter data instead of 1-minute average SCADA meter data, which is currently used. In addition, BPA proposes a formula rate adjustment to the DERBS rate to recover the cost of any planned purchases of non-Federal balancing reserve capacity that are necessary to provide DERBS and VERBS. BPA also proposes to exempt specific 5-minute average periods from the DERBS rate calculation
for schedule deviations that were caused by automatic voltage control systems that corrected a grid frequency
deviation.

BPA proposes to change the
calculation of its incremental cost for Energy and Generation Imbalance Services from an hourly market index to a weighted average cost of energy deployed. BPA also proposes to provide no credit for generator imbalances (actual generation exceeds scheduled amounts) under Generation Imbalance Service that occur during a scheduling period in which BPA issues a curtailment order. In addition, BPA proposes to exempt customers that participate in committed intra-hour scheduling from Deviation Band 2 penalty charges under Generation Imbalance Service. Finally, BPA proposes to exempt customers that participate in committed intra-hour scheduling or committed hourly scheduling from the Persistent Deviation penalty charge.

c. DSI Service for FY 2014–2015

In the Initial Proposal, BPA is forecasting sales of 312 aMW to Alcoa and Port Townsend Paper for the FY 2014–2015 rate period. BPA proposedand received public comment on a tenyear contract with Port Townsend Paper that would provide service through FY 2022. BPA is currently receiving public comment on a proposed ten-year
contract with Alcoa that would also provide service through FY 2022. The Initial Proposal does not make an explicit assumption about the outcome of either proposed contract; however, the Initial Proposal does assume that
BPA will serve the two industries during the forthcoming rate period.

d. Risk Mitigation Tools

The main financial risk mitigation tool BPA relies upon is financial liquidity, comprising cash, other
investments in the Bonneville Fund at the U.S. Treasury, and a short-term liquidity facility with the U.S. Treasury. BPA proposes to include provisions for two rate adjustments: the Cost Recovery Adjustment Clause (CRAC), which can generate additional cash within the rate period, and the Dividend Distribution Clause (DDC), which can return cash to
customers when BPA’s financial reserves are larger than needed to meet its Treasury Payment Probability (TPP) standard. When available liquidity and
the CRAC are insufficient to meet the TPP standard, BPA includes Planned


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Net Revenues for Risk (PNRR) in its

rates.

In the Initial Proposal, BPA proposes to include no PNRR and to cap the maximum revenue recoverable through the CRAC at $300 million per year. BPA is proposing some minor changes to the risk mitigation tools in the BP–14 Initial Proposal, including a revision to the
metric used to determine whether a CRAC or DDC triggers. The thresholds for triggering the CRAC and DDC remain unchanged from the BP–12 rate case (equivalent reserve levels of $0 and $750 million respectively in financial reserves attributed to Power). BPA also proposes to continue the National
Marine Fisheries Service FCRPS Biological Opinion Adjustment (NFB Adjustment) and the Emergency NFB Surcharge, given that litigation regarding the Biological Opinion

continues.

B. Summary of the Transmission Rate Proposal

1. Transmission Rates

BPA is proposing an overall 13 percent increase in transmission rates. This increase includes a proposed 25 percent increase in the Utility Delivery

rate.

BPA is proposing four different rates for the use of its Integrated Network segment, four different rates for use of intertie segments, and several other rates for various purposes.

The four rates for use of the Integrated Network segment are:

Formula Power Transmission Rate (FPT–14)—The FPT rate is based on the cost of using specific types of facilities, including a distance component for the use of transmission lines, and is charged
on a contract demand basis.

Integration of Resources Rate (IR– 14)—The IR rate is a postage stamp,
contract demand rate for the use of theIntegrated Network, similar to Point-toPoint (PTP) service (see below).

Network Integration Transmission Rate (NT–14)—The NT rate applies to customers taking network integration service under the Open Access Transmission Tariff (OATT) and allows customers to flexibly serve their retail
load.

Point-to-Point Rate (PTP–14)—The
PTP rate is a contract demand rate thatapplies to customers taking point-topoint service on BPA’s network facilities under the OATT. It provides
customers with flexible service from identified Points of Receipt to identified Points of Delivery. There are separate PTP rates for long-term firm service; daily firm and non-firm service; and hourly firm and non-firm service. BPA is proposing four rates for

intertie use:

The Southern Intertie Rate (IS–14) and the Montana Intertie Rate (IM–14) are contract demand rates that apply to customers taking Point-to-Point service
under the OATT on the Southern
Intertie and Montana Intertie. These rates are structured similarly to the rate
for Point-to-Point service on Network
facilities.

The Townsend-Garrison Transmission Rate (TGT–14) and the Eastern Intertie Rate (IE–14) are developed pursuant to the Montana Intertie agreement.

Other proposed transmission rates

are:

The Use-of-Facilities Rate (UFT–14) establishes a formula for charging for the use of a specific facility based on the annual cost of that facility.

The Advance Funding Rate (AF–14)
allows Transmission Services to collect the capital and related costs of specific facilities through an advance-funding
mechanism.

Other charges that may apply includea Delivery Charge for the use of lowvoltage delivery substations; a Power Factor Penalty Charge; a Reservation Fee for customers that postpone their service commencement dates;
incremental rates for transmission requests that require new facilities; a penalty charge for failure to comply with dispatch, curtailment, redispatch, or load shedding orders; and an Unauthorized Increase Charge for
customers that exceed their contracted

amounts.

2. Ancillary and Control Area Services

Rates

BPA is proposing rates for six ancillary services: Scheduling, System Control, and Dispatch Service; Reactive Supply and Voltage Control from Generation Sources Service; Regulation and Frequency Response Service; Energy Imbalance Service; Operating Reserve–Spinning Reserve Service; and, Operating Reserve–Supplemental
Reserve Service. In addition to the rates for Ancillary Services, BPA is proposing
rates for six control area services: Regulation and Frequency Response Service; Generation Imbalance Service; Operating Reserve–Spinning Reserve Service; Operating Reserve– Supplemental Reserve Service; Variable Energy Resource Balancing Service; and Dispatchable Energy Resource Balancing

Service. 3. Significant Changes in the BP–14 Initial Rate Proposal for Transmission

Rates

a. Network Cost Allocation

BPA is proposing to change its cost allocation methodology for allocating Integrated network costs to NT and PTP rates from a 1 coincidental peak (1CP) method to a 12 non-coincidental peak (12 NCP) method. The rate impact of this change is approximately a 1.5 percent increase in the PTP rate and a 5.9 percent decrease in the NT rate.

b. Billing Determinants for NT and Utility Delivery Service

BPA is proposing to change the billing determinants for NT service and Utility Delivery service to be consistent with
the Network cost allocation methodology.

Changes to ancillary and control area
services rates are discussed in section
IV.A.2.b.

C. Overview of Studies

The initial rate proposal for power rates, transmission rates, and ancillary
service and control area service rates is explained and documented in the following studies.

1. Power Rates Study

The Power Rates Study explains and documents the development of power rates and billing determinants for BPA’s power products and services. The results of the study are reflected in the proposed power rate schedules.

2. Power Loads and Resources Study

The Power Loads and Resources Study explains and documents the compilation of the load and resource data and forecasts necessary for developing BPA’s wholesale power rates. The Study has three major interrelated components: the Federal system load forecast; the Federal system resource forecast; and the Federal system loads and resources balance.

3. Power Revenue Requirement Study

The Power Revenue Requirement Study explains and documents the level of revenues from power rates necessary to recover, in accordance with sound business principles, the FCRPS costs associated with the production, acquisition, marketing, and conservation of electric power. Cost
estimates in the Power Revenue Requirement Study are based on the results of the IPR, as presented in the Final Close-Out Report dated October 26, 2012. The repayment studies reflect actual and projected repayment obligations and transactions related to


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BPA’s Debt Optimization program. All new capital investments are assumed to be financed from debt or appropriations. The adequacy of projected revenues to recover the rate test period revenue requirement and to recover the Federal investment over the prescribed repayment period is tested and demonstrated for the generation
function.

4. Power Risk and Market Price Study

The Power Risk and Market Price Study has three major components: the electricity market price forecast used in setting power rates; the quantification of the risks accounted for in setting power rates; and the set of risk mitigation
measures to include in rates that ensure that power rates meet the established
TPP. The TPP is a measure of the probability that BPA will make its Treasury payments on time and in full during the rate period. If the TPP is below BPA’s two-year 95 percent standard, a combination of risk mitigation tools is proposed to meet the
TPP standard.

The electricity market price forecast portion of the study explains and
documents forecasts of the variable cost of the marginal resource for transactions in the wholesale energy market. Themarket used in this analysis is the MidColumbia trading hub in the state of Washington, although this forecast is influenced by conditions in other regions within the Western
Interconnection. The Power Risk and Market Price Study also explains and documents the natural gas price forecast used in setting rates.

5. Generation Inputs Study

The Generation Inputs Study includes the study and documentation forgeneration inputs costs and other interbusiness line costs. The study also includes the development and design of the proposed ACS–14 Ancillary and
Control Area Services rate schedule. The forecasts for balancing reserve capacity to provide regulation and frequency response, variable energy resource balancing service, dispatchable energy resource balancing service, operating reserve, and load following are explained and documented in the Generation Inputs Study. The Study explains and documents the embedded and variable cost methodologies for these balancing reserve capacity obligations and the resulting revenue credits reflected in the power rates.

6. Transmission Rates Study (TRS)

The Transmission Rates Study explains the rate design process for developing transmission, ancillary and control area service rates. The purpose
of the TRS is to derive rates that will
recover transmission costs. The rate study also explains proposed changes to
the Transmission Service Rate
Schedules and General Rate Schedule

Provisions.

7. Transmission Revenue Requirement Study

The Transmission Revenue Requirement Study establishes the level
of revenue needed from transmission rates to recover, in accordance with sound business principles, the costs
associated with the transmission of electric power. The Transmission Revenue Requirement Study includes a risk analysis to ensure that the proposed
transmission rates are sufficient to achieve a 95 percent probability of making end-of-year U.S. Treasury payments in full and on time during the two-year rate period.

8. Transmission Segmentation Study

The Transmission Segmentation Study classifies transmission facilities by usage and assigns them to segments. Segments are groups of facilities that serve distinct functions (for example, integration of power into the transmission system or delivery of power at low voltage). The Segmentation Study also determines the plant investment and historical operations and maintenance expense for each segment based on the facilities that have been assigned to that segment.

Part V—Proposed 2014 Rate Schedules

BPA’s proposed 2014 Power Rate Schedules and proposed 2014 Transmission Rate Schedules are a part
of this notice and are available for viewing and downloading on BPA’s
Web site at www.bpa.gov/goto/
BP14Schedule. Copies of the proposed
rate schedules also are available for viewing in BPA’s Public Reference Room at the BPA Headquarters, 1st Floor, 905 NE 11th Avenue, Portland,

OR 97232.

Issued this 29th day of October, 2012.
Stephen J. Wright,
Administrator and Chief Executive Officer.

[FR Doc. 2012–27299 Filed 11–7–12; 8:45 am]

**BILLING CODE 6450–01–P DEPARTMENT OF ENERGY** 

**Federal Energy Regulatory**
**Commission**

**Combined Notice of Filings**

Take notice that the Commission has received the following Natural Gas Pipeline Rate and Refund Report filings:

Filings Instituting Proceedings

Docket Numbers: CP13–9–000. Applicants: Dominion Transmission,

Inc.

Description: Application to Abandon Gas Transportation with NSTAR of Dominion Transmission, Inc.

Filed Date: 10/25/12.
Accession Number: 20121025–5162. Comments Due: 5 p.m. ET 11/6/12.

Docket Numbers: RP13–196–000. Applicants: Gulf South Pipeline Company, LP.

Description: Withdraw filing in
Docket No. RP13–196–000.

Filed Date: 10/31/12.
Accession Number: 20121031–5039. Comments Due: 5 p.m. ET 11/13/12.

Docket Numbers: RP13–208–000. Applicants: Gulf South Pipeline Company, LP.

Description: EFT to FTS One Time Conversion filing to be effective 12/1/

2012.

Filed Date: 10/31/12.
Accession Number: 20121031–5060. Comments Due: 5 p.m. ET 11/13/12.

Docket Numbers: RP13–209–000. Applicants: Gulf South Pipeline Company, LP.

Description: Create Umbrella Service
to be effective 12/3/2012.

Filed Date: 10/31/12.
Accession Number: 20121031–5064. Comments Due: 5 p.m. ET 11/13/12.

Docket Numbers: RP13–210–000. Applicants: Gulf South Pipeline Company, LP.

Description: Agent Agreement Option filing to be effective 12/1/2012.

Filed Date: 10/31/12.
Accession Number: 20121031–5065. Comments Due: 5 p.m. ET 11/13/12.

Docket Numbers: RP13–211–000. Applicants: Boardwalk Storage Company, LLC.

Description: Cancellation of First
Revised Volume No. 1 to be effective 10/
31/2012.

Filed Date: 10/31/12.
Accession Number: 20121031–5068. Comments Due: 5 p.m. ET 11/13/12.

Docket Numbers: RP13–212–000. Applicants: Boardwalk Storage Company, LLC.

Description: Baseline filing of Second
Revised Volume No. 1 to be effective 10/
1/2012.