66966 Federal Register / Vol. 77, No. 217 / Thursday, November 8, 2012 / Notices 

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 transmission 

system, 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 (Business 

Plan 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 Plan 

EIS’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 net 

requirements 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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Federal Register / Vol. 77, No. 217 / Thursday, November 8, 2012 / Notices 66971 

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 is 

based 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 and 

decrease 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) for 

the 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 proposed 

and 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 


tkelley on DSK3SPTVN1PROD with NOTICES
66972 Federal Register / Vol. 77, No. 217 / Thursday, November 8, 2012 / Notices 

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 the 

Integrated 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 that 

applies 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 include 

a 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 


tkelley on DSK3SPTVN1PROD with NOTICES
Federal Register / Vol. 77, No. 217 / Thursday, November 8, 2012 / Notices 66973 

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. The 

market 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 for 

generation 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. 


tkelley on DSK3SPTVN1PROD with NOTICES