2007 Supplemental Wholesale Power Rate Adjustment Proceeding, Public Hearings, and Opportunities for Public Review and Comment, 7539-7555 [E8-2339]
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Federal Register / Vol. 73, No. 27 / Friday, February 8, 2008 / Notices
Department’s program, financial and
procurement personnel to evaluate
proposals and administer contracts.
These collections are used to exercise
management oversight and control of
the Department’s management
contractors operating the Department’s
major facilities and other contractors
furnishing goods and services; (5)
Respondents: 7,539; (6) Estimated
Number of Burden Hours: 896,209.
Statutory Authority: Section 644 of
the Department of Energy Organization
Act, 42 U.S.C. 7254, and section 205(c)
of the Federal Property and
Administrative Services Act, 40 U.S.C.
486(c).
Issued in Washington, DC on February 1,
2008.
Edward R. Simpson,
Director, Office of Procurement and
Assistance Management.
[FR Doc. E8–2341 Filed 2–7–08; 8:45 am]
BILLING CODE 6450–01–P
DEPARTMENT OF ENERGY
Bonneville Power Administration
2007 Supplemental Wholesale Power
Rate Adjustment Proceeding, Public
Hearings, and Opportunities for Public
Review and Comment
Bonneville Power
Administration (BPA), Department of
Energy (DOE).
ACTION: Notice of Proposed Wholesale
Power Rates (Notice). BPA File No.:
WP–07.
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AGENCY:
SUMMARY: 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 they are adequate to recover, in
accordance with sound business
principles, the costs associated with the
acquisition, conservation and
transmission of electric power, and to
recover the Federal investment in the
Federal Columbia River Power System
(FCRPS) and other costs incurred by
BPA. BPA is reopening its WP–07
wholesale power rate proceeding, which
established power rates for Fiscal Years
(FY) 2007–2009, in order to respond to
recent decisions from the United States
Court of Appeals for the Ninth Circuit
(Ninth Circuit or Court) and to revise
rates for FY 2009.
This 2007 Supplemental Wholesale
Power Rate Adjustment Proceeding
(WP–07 Supplemental Proceeding)
responds to the Court’s remand of BPA’s
WP–02 power rates for FY 2002–2006.
This proceeding also responds to a
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separate Court decision that found
BPA’s 2000 Residential Exchange
Program (REP) Settlement Agreements
(REP Settlement Agreements) contrary
to law. In response, BPA proposes to
determine the amounts of REP
settlement costs improperly included in
FY 2002–2008 power rates, recover
those amounts from investor owned
utility customers (IOUs) over time and
return improperly included amounts to
preference customers. The WP–07
Supplemental Proceeding also includes
proposed revisions to BPA’s Section
7(b)(2) Legal Interpretation and Section
7(b)(2) Implementation Methodology.
Persons that previously intervened in
BPA’s WP–07 Wholesale Power Rate
Adjustment Proceeding automatically
continue their party status in the WP–
07 Supplemental Proceeding. Other
persons wishing to become a formal
party to the proceeding must file a
petition to intervene, notifying BPA in
writing of their intention to do so in
conformance with the requirements
stated in this Notice.
DATES: Petitions to intervene must be
received no later than 5 p.m., Pacific
Standard Time, on February 18, 2008.
Non-party participants may make
written comments between February 8,
2008, and May 5, 2008. Comments must
be received by 5 p.m., Pacific Daylight
Savings Time, on May 5, 2008, in order
to be considered in the Supplemental
Record of Decision (Supplemental
ROD). (See Part III (A) for more
information.)
ADDRESSES: Petitions to intervene
should be directed to Robert Welsh,
Hearing Clerk, LP–7, Bonneville Power
Administration, 905 NE 11th Avenue,
Portland, OR 97232 or by e-mail to:
wp07rate@bpa.gov. In addition, a copy
of the petition must be served
concurrently on BPA’s General Counsel
and directed to Kurt R. Casad, LP–7,
Office of General Counsel, Bonneville
Power Administration, 905 NE 11th
Avenue, Portland, OR 97232 or by email to: krcasad@bpa.gov. See Part III
(A) for more information.) Written
comments by non-party participants
must be received by 5 p.m. Pacific
Daylight Savings Time, on May 5, 2008,
in order to be considered in the
Supplemental Record of Decision
(Supplemental ROD). Written comments
may be made as follows: In person at the
field hearings (see schedule and
locations in Part I of this Notice), online
at BPA’s Web site: https://www.bpa.gov/
comment, or by mail to: BPA Public
Affairs, DKE–7, P.O. Box 14428,
Portland, OR 97293–4428. Please
identify written or electronic comments
as ‘‘WP–07 Supplemental Proceeding.’’
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7539
The Supplemental ROD will consider
and address the comments received.
The WP–07 Supplemental Proceeding
will begin with a prehearing conference
at 9 a.m., Pacific Standard Time, on
February 19, 2008, held in the BPA
Rates Hearing Room, 2nd Floor, 911 NE
11th Avenue, Portland, OR. Due to
increased security requirements,
attendees should allow additional time
to enter the building and complete the
required screening process. Photo
identification will be required for entry.
BPA will release its 2007 Supplemental
Wholesale Power Rate Proposal (WP–07
Supplemental Proposal) and supporting
documents at the prehearing conference.
Compact discs (CDs) containing the
WP–07 Supplemental Proposal will be
provided to the parties at the prehearing
conference. The WP–07 Supplemental
Proposal will also be available on BPA’s
Web site at https://www.bpa.gov/
corporate/ratecase.
FOR FURTHER INFORMATION CONTACT:
Ms. Heidi Helwig, Public Affairs
Specialist, Public Affairs Office, DKE–
7, P.O. Box 3621, Portland, OR 97208.
Interested persons may also call 503–
230–3458 or 1–800–622–4519 (tollfree)
Ms. Leslie M. Dimitman, Paralegal
Specialist, Office of General Counsel,
LP–7, P.O. Box 3621, Portland, OR
97208. Interested persons may also
call Ms. Dimitman at (503) 230–5515,
or the general BPA toll-free numbers
1–800–282–3713 (answered Monday
through Friday 6:30 a.m. to 5 p.m.) or
1–866–879–2303 (answered by
voicemail)
Information also may be obtained
from:
Mr. Raymond D. Bliven, Power Rates
Manager—PFR–6, P.O. Box 3621,
Portland, OR 97208
Ms. Suzanne B. Cooper, Power Policy
and Rates Manager—PF–6, P.O. Box
3621, Portland, OR 97208
Ms. Elizabeth Evans, Policy Analysis
Manager—PFB–6, P.O. Box 3621,
Portland, OR 97208
Mr. Garry Thompson, Manager, Eastern
Power Business Area; Mr. Ken
Hustad, Senior Customer Account
Executive; Ms. Carol Hustad,
Customer Account Executive; Mr.
Michael Normandeau, Customer
Account Executive, Eastern Power
Business Area—PSE, 707 W. Main,
Suite 500, Spokane, WA 99201
Mr. Scott Coe, Manager, Western Power
Business Area; Mr. Charles Forman,
Customer Account Executive; Ms.
Claire Hobson, Customer Account
Executive; Ms. Tina Ko, Customer
Account Executive; Ms. Theresa
Rockwood, Customer Account
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Executive; Western Power Business
Area—PSW–6, P.O. Box 3621,
Portland, OR 97208
Mr. Larry King, Customer Account
Executive, 2700 Overland, Burley, ID
83318
Mr. C. T. Beede, Customer Account
Executive, P.O. Box 40, Big Arm, MT
59910
Mr. Dan Bloyer, Customer Account
Executive, 1011 SW Emkay Drive,
Suite 211, Bend, OR 97702
Mr. Larry Felton, Senior Account
Executive, Kootenai Building, Room
215, N. Power Plant Loop, Richland,
WA 99352–0968
Mr. Stuart Clarke, Senior Customer
Account Executive; Mr. George Reich,
Senior Customer Account Executive;
Ms. Shannon Greene, Customer
Account Executive; Ms. R. Kirsten
Watts, Customer Account Executive;
909 First Avenue, Suite 380, Seattle,
WA 98104–3636
SUPPLEMENTARY INFORMATION:
Table of Contents
I. Introduction and Procedural Background
II. Policy Guidance and Scope of Hearing
III. Public Participation
IV. Summary of WP–07 Supplemental
Proposal and Major Studies
V. Section 7(b)(2) Legal Interpretation and
Implementation Methodology
VI. Summary of Proposal To Respond to the
Court’s Opinions Regarding BPA’s 2000
REP Settlement Agreements, WP–02
Rates, and by Extension, WP–07 Rates
VII. 2007 Supplemental Wholesale Power
Rate Case Schedules (FY 2009) and 2007
Supplemental General Rate Schedule
Provisions (FY 2009)
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Part I—Introduction and Procedural
Background
A. Overview and Background to This
Rate Filing
BPA is proposing to conduct a WP–
07 Supplemental Proceeding in order to:
(1) Adjust BPA’s FY 2009 power rates
consistent with recent decisions of the
Ninth Circuit regarding BPA’s WP–02
power rates for FY 2002–2006; and (2)
respond to the Court’s decision finding
BPA’s REP Settlement Agreements
contrary to the Northwest Power Act.
Due to the time it takes to conduct a
general rate adjustment proceeding,
BPA determined that its first
opportunity to establish revised power
rates to conform to the Court’s opinions
was prior to the one-year FY 2009 rate
period. Because BPA’s WP–07 rates (FY
2007–2009) are currently before the
Federal Energy Regulatory Commission
(FERC) for final approval, BPA asked
FERC to stay its review until BPA was
able to conduct a supplemental rate
proceeding to address the issues noted
above. This will permit FERC to review
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a single supplemented record
supporting BPA’s proposed rates for FYs
2007, 2008, and 2009.
In developing BPA’s WP–02 power
rates, BPA’s revenue requirement
included anticipated costs of REP
Settlement Agreements with six regional
IOUs. BPA allocated the majority of
these settlement costs to the Priority
Firm Power (PF) Preference rate.
Following final approval of BPA’s WP–
02 rates by FERC, a number of parties
challenged the WP–02 power rates in
the Ninth Circuit. In Golden NW
Aluminum, Inc. v. Bonneville Power
Admin., 501 F.3d 1037 (9th Cir. 2007)
(Golden NW), the Court held BPA had
improperly allocated REP Settlement
Agreement costs to BPA’s rates for
preference customers. During the
litigation of Golden NW, but prior to the
Court’s decision, BPA conducted a
subsequent hearing (WP–07) to establish
power rates for FY 2007–2009. In
establishing these rates, BPA allocated
REP settlement costs in the same
manner as in BPA’s WP–02 rates.
Because the Court held in Golden NW
that BPA’s allocation of REP settlement
costs in its WP–02 rates was improper,
BPA’s allocation of such costs in the
WP–07 rates is similarly flawed.
In addition, the Court held that BPA’s
WP–02 fish and wildlife cost estimates,
and by extension the rates set pursuant
to those estimates, were not supported
by substantial evidence. The Court
indicated BPA relied on outdated
assumptions and had not appropriately
considered information presented
regarding its fish and wildlife costs.
BPA’s subsequent approach to
forecasting fish and wildlife costs in the
development of its WP–07 rates differed
from the approach BPA used in
developing its WP–02 rates.
Nonetheless, as described in more detail
in Part II.A.5, BPA is taking steps to
ensure that its final WP–07
Supplemental rates for FY 2009 are
based on the most recent projections of
fish and wildlife costs available at the
time of rate development. In a
procedural forum separate from the
WP–07 Supplemental Proceeding, BPA
will provide opportunities for fish and
wildlife managers and others to provide
input to BPA regarding BPA’s fish and
wildlife program costs for FY 2009.
Decisions made based on the
information gained from this separate
program cost review forum will be used
in the development of BPA’s final WP–
07 Supplemental rates.
In a companion case to Golden NW,
the Court held that BPA’s REP
Settlement Agreements with the IOUs
were contrary to the Northwest Power
Act. Portland General Elec. Co. v.
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Bonneville Power Admin., 501 F.3d
1009 (9th Cir. 2007) (PGE). Also,
subsequent to the Golden NW and PGE
decisions, the Court reviewed three
petitions for review challenging Load
Reduction Agreements (LRAs) BPA
executed with two IOUs during the
energy crisis of 2000–2001. The Court
dismissed two of the petitions for lack
of jurisdiction and one petition as moot.
The Court also reviewed challenges to
amendments to the REP Settlement
Agreements signed in 2004. In Public
Utility Dist. No. 1 of Snohomish County,
Wash. v. Bonneville Power Admin., 506
F.3d 1145 (9th Cir. 2007) (Snohomish),
the Court remanded the amendments
and a contract provision establishing a
Reduction of Risk Discount to BPA. BPA
must respond to the foregoing decisions.
Because the ratemaking and REP issues
are interrelated, BPA is proposing to
address its response to the Court’s
decisions in the WP–07 Supplemental
Proceeding.
In summary, this WP–07
Supplemental Proceeding is being held
for four primary purposes: (1) To
establish new power rates for FY 2009;
(2) to determine the amount of benefits
that BPA’s IOU customers received, or
would have received, from FY 2002
through FY 2008 under REP settlements;
(3) to determine the amount of REP
benefits the IOUs would have received
in the absence of the REP settlements;
and (4) to address any difference
between these two amounts.
Specifically, the revised power rates for
FY 2009 include the PF Preference rate
and the PF Exchange rate. The average
PF Preference rate of $26.2/MWh, about
a four percent (4%) reduction, results
largely from the reduced REP costs. The
revised PF Exchange rate is used to
determine REP benefits in FY 2009 As
part of this process, BPA is also
proposing revisions to BPA’s Section
7(b)(2) Legal Interpretation and Section
7(b)(2) Implementation Methodology.
An introduction to BPA’s WP–07
Supplemental Proposal is contained in
Part IV of this Notice. A summary of
BPA’s proposal regarding the
calculation of REP benefits for FY 2002–
2008 is contained in Part VI.
B. Legal Requirements
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. These procedures
include, among other things:
publication of a notice of the proposed
rates in the Federal Register; one or
more hearings conducted as
expeditiously as practicable by a
Hearing Officer; public opportunity to
provide both oral and written views
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related to the proposed rates;
opportunity to offer refutation or
rebuttal of submitted material; and a
decision by the Administrator based on
the record. This proceeding is governed
by § 1010 of BPA’s Rules of Procedure
Governing Rate Hearings, 51 FR 7611
(1986) (BPA Hearing Procedures). These
procedures implement the statutory
section 7(i) requirements.
Section 1010.7 of the BPA Hearing
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 BPA’s rate case by other
Executive Branch agencies, Congress,
existing or potential BPA customers
(including tribes), and nonprofit or
public interest groups are considered
outside communications and are subject
to the ex parte rule. The general rule
does not apply to communications
relating to: (1) Matters of procedure only
(the status of the rate case, 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 BPA is
responsible for under statutes other than
the ratemaking provisions; or (5) matters
that 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 August 18, 2008.
The Bonneville Project Act, 16 U.S.C.
832, the Flood Control Act of 1944, 16
U.S.C. 825s, the Federal Columbia River
Transmission System Act, 16 U.S.C.
838, and the Northwest Power Act, 16
U.S.C. 839, provide guidance regarding
BPA ratemaking. The Northwest Power
Act requires BPA to set rates that are
sufficient to recover, in accordance with
sound business principles, the cost of
acquiring, conserving and transmitting
electric power, including amortization
of the Federal investment in the FCRPS
over a reasonable period of years, and
certain other costs and expenses
incurred by the Administrator.
BPA’s 2007 Supplemental Wholesale
Power Rate Schedules (FY 2009) and
2007 Supplemental General Rate
Schedule Provisions (GRSPs) (FY 2009),
as well as the Section 7(b)(2) Legal
Interpretation and Section 7(b)(2)
Implementation Methodologye, are
available for viewing and downloading
on BPA’s Web site at https://
www.bpa.gov/corporate/ratecase as
discussed in Part VII of this Notice. The
studies addressing the factors used to
develop these rates are listed in Part IV
and will be available for examination
beginning February 19, 2008, at BPA’s
Public Information Center, BPA
Headquarters Building, 1st Floor, 905
NE 11th Avenue, Portland, Oregon, and
will be provided to parties at the
prehearing conference to be held on
February 19, 2008, beginning at 9 a.m.,
Pacific Standard Time, Room 223, 911
NE 11th Avenue, Portland, Oregon.
Copies of the studies and
documentation can be downloaded from
BPA’s Web site at https://www.bpa.gov/
corporate/ratecase or can be requested
(on a compact disc or hard copy) by
calling BPA’s document request line
toll-free at: 1–800–622–4519.
A formal evidentiary rate hearing will
be conducted that is open to rate case
parties. Interested parties that did not
previously intervene in BPA’s WP–07
power rate proceeding must file
petitions to intervene in order to take
part in the WP–07 formal hearing. A
proposed schedule for the WP–07
Supplemental Proceeding is stated
below.
The Hearing Officer will establish a
final schedule at the prehearing
conference.
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Prehearing/BPA Direct Case ..............................................................................................................................................
Clarification ........................................................................................................................................................................
Motions to Strike ................................................................................................................................................................
Data Request Deadline .......................................................................................................................................................
Answers to Motions to Strike ............................................................................................................................................
Data Response Deadline .....................................................................................................................................................
Spokane, WA Field Hearing ..............................................................................................................................................
Portland, OR Field Hearing ...............................................................................................................................................
Parties file Direct Cases ......................................................................................................................................................
Clarification ........................................................................................................................................................................
Motions to Strike ................................................................................................................................................................
Data Request Deadline .......................................................................................................................................................
Answers to Motions to Strike ............................................................................................................................................
Data Response Deadline .....................................................................................................................................................
Litigants file Rebuttal .........................................................................................................................................................
Close of Participant Comments .........................................................................................................................................
Clarification ........................................................................................................................................................................
Motions to Strike ................................................................................................................................................................
Data Request Deadline .......................................................................................................................................................
Answers to Motions to Strike ............................................................................................................................................
Data Response Deadline .....................................................................................................................................................
Cross-Examination ..............................................................................................................................................................
Initial Briefs Filed ..............................................................................................................................................................
Oral Argument ....................................................................................................................................................................
Publish Draft ROD ..............................................................................................................................................................
Briefs on Exceptions ...........................................................................................................................................................
Publish Final ROD—Final Studies ....................................................................................................................................
As noted above, BPA will conduct
two public field hearings in the Pacific
Northwest. Public field hearings are an
opportunity for persons who are not
parties in the formal rate hearing to have
their views included in the official
record. Written transcripts will be made
at all of the field hearings. The field
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hearings have been scheduled to take
place at the locations, dates, and times
specified below. The hearing dates also
will be posted on the BPA’s Web site
(https://www.bpa.gov/corporate/
ratecase) and through announcements
in local newspapers. Any changes to the
scheduled public hearings will be
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02/19/08
02/27/08–02/29/08
03/07/08
03/07/08
03/14/08
03/14/08
03/18/08
03/20/08
03/28/08
04/07/08–04/09/08
04/11/08
04/11/08
04/18/08
04/18/08
05/05/08
05/05/08
05/12/08–05/14/08
05/15/08
05/15/08
05/22/08
05/22/08
05/27/08–05/30/08
06/09/08
06/16/08–06/17/08
07/16/08
07/28/08
08/18/08
available on the rate case Web site. The
BPA Public Affairs Office also may be
contacted for this information at the
telephone number previously listed.
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PUBLIC FIELD HEARINGS SCHEDULE
03/18/08 ...
6 p.m. ..
03/20/08 ...
6 p.m. ..
Spokane, Washington.
Portland, Oregon.
Part II—Policy Guidance and Scope of
Hearing
A. Policy Guidance
The following policies are
foundational elements that guided the
development of major components of
this supplemental rate proposal.
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1. BPA’s Subscription Strategy
On December 21, 1998, BPA issued a
Power Subscription Strategy and Record
of Decision (Subscription Strategy). The
Subscription Strategy reflected BPA’s
position on the equitable distribution of
Federal power for FY 2002–2011. The
Subscription Strategy was the
culmination of a multi-year public
process that established BPA’s plan for
the availability of Federal power post2001, the products from which
customers could choose, and an outline
of the contracts and pricing framework
for those products.
The Subscription Strategy provided a
marketing framework for the WP–02 and
WP–07 power rate cases. The WP–02
and WP–07 power rate cases developed
the rate schedules necessary for the
products and contracts that were
developed through Subscription. The
Subscription contracts, except for the
REP Settlement Agreements, continue to
be the basis for the contractual
relationship between BPA and nearly all
of its firm power customers. BPA is
assuming for purposes of this WP–07
Supplemental Proceeding that the IOUs,
except Idaho Power Company (Idaho
Power), would have signed Residential
Purchase and Sale Agreements (RPSAs)
in the fall of 2000 instead of the 2000
REP Settlement Agreements.
2. Regional Dialogue and the Near-Term
and Long-Term Policies
The Regional Dialogue process began
in April 2002 when a group of BPA’s
Pacific Northwest electric utility
customers submitted a ‘‘joint customer
proposal’’ to BPA that addressed both
near-term and long-term contract and
rate issues. Since then, BPA, the
Northwest Power and Conservation
Council (Council), customers, and other
interested parties have worked on these
near- and long-term issues. Considering
the depth and complexity of many of
these issues, BPA concluded it was not
practical to resolve all issues before the
start of the WP–07 rate case. Therefore,
BPA determined that it would address
the issues in two phases. The first phase
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of the Regional Dialogue, referred to as
the Near-Term Policy, addressed issues
that had to be resolved in order to
replace power rates that expired in
September 2006. See Bonneville Power
Administration’s Policy for Power
Supply Role for Fiscal Years 2007–2011
(February 2005). The issues in the
second phase were addressed in BPA’s
Long-Term Regional Dialogue Final
Policy and Record of Decision, which
was published on July 19, 2007. The
Long-Term Regional Dialogue Final
Policy is expected to be implemented
through new power sales contracts and
a future rate case conducted before such
contracts go into effect in FY 2012. The
Long-Term Regional Dialogue Final
Policy does not affect this WP–07
Supplemental Proceeding.
3. Service to Direct Service Industries
(DSIs)
The Near-Term Policy established
parameters for service to the DSIs that
were further addressed in ‘‘Bonneville
Power Administration’s Service to DSI
Customers for Fiscal Years 2007–2011,
Administrator’s Record of Decision’’
(DSI ROD) (June 30, 2005), and
Supplement to Administrator’s Record
of Decision on Bonneville Power
Administration’s Service to Direct
Service Industrial (DSI) Customers for
Fiscal Years 2007–2011, Administrator’s
Record of Decision (May 31, 2006),
(together the ‘‘DSI RODs’’).
In the DSI RODs, BPA determined to
offer to aluminum company DSIs power
sales contracts for an aggregate 560
aMW of benefits at a capped cost of $59
million. In addition, BPA offered a 17
aMW surplus firm power sales contract
for Port Townsend Paper Company
through the local public utility under
the FPS rate (or the Industrial Firm
Power (IP) rate, if viable) at a price
approximately equivalent to, but in no
case less than, its lowest-cost PF rate.
BPA decided to allocate a share of the
560 aMW of service benefits to each DSI
aluminum company for purposes of
making an initial offer of service.
Because of the financial risks inherent
in providing actual power and in order
to meet the known and capped cost
prerequisite, BPA determined that the
delivery mechanism would be to
monetize the value of the below-market
power sales to provide service benefits
through cash payments.
4. Power Function Review and Other
Cost Reviews
In January 2005, BPA initiated an
extensive process, known as the Power
Function Review (PFR), to examine
Power Services’ (formerly known as
Power Business Line or PBL) intended
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program spending levels. The PFR
process consisted of two phases
designed to give interested parties an
opportunity to examine, understand and
provide input on the cost projections
that would form the basis for BPA’s
WP–07 Power Rate Proposal. The first
phase concluded in June 2005 when
BPA issued the PFR Final Report. At
that time, BPA committed to re-examine
the program levels prior to establishing
power rates in BPA’s final proposal. In
early 2006, BPA conducted the second
phase, known as PFR II, allowing
interested parties an opportunity to
review these program levels. Workshops
were held during January through
March, 2006 and in April of 2006, BPA
issued a draft closeout report for
comment. After the close of comment,
BPA reviewed all comments and issued
the PFR II Final Closeout Report
documenting BPA’s decisions on June 1,
2006. These updated program levels
were then incorporated into BPA’s WP–
07 Final Proposal.
5. Mid-WP–07 Rate Period Cost Forecast
Changes
For the WP–07 Supplemental
Proceeding, BPA reviewed the FY 2009
program levels incorporated into the
WP–07 Final Proposal that were
developed through the PFR I and II
processes. BPA then evaluated whether
these forecasts remain reasonable in
light of current projections. From this
evaluation, BPA determined that
adjustments were needed in certain
program areas to address significant
changes in forecast program levels.
Specifically, these cost areas include:
The Residential Exchange Program;
Columbia Generating Station (CGS)
operation and maintenance; interest;
amortization; depreciation; renewables;
energy efficiency; long-term generating
projects; augmentation; purchased
power; and fish and wildlife costs. BPA
described the nature of the non-REP cost
changes to interested persons in a
public workshop on October 10, 2007.
In the October workshop, BPA
notified attendees that it intended to
initiate a separate public process to
address possible changes to the fish and
wildlife cost forecast for FY 2009, 1 costs
of operating the CGS, and other cost
changes identified that are relevant to
the WP–07 Supplemental Proceeding. In
1 Such changes could result from, for example,
the issuance by NOAA Fisheries of a final
Biological Opinion regarding the impacts of the
mainstem Federal Columbia River Power System
dams on threatened and endangered salmon and
steelhead, and from any related commitments BPA
may make in a long-term Memoranda of Agreement
currently being discussed with some regional
governmental entities.
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6. Post-2006 Conservation Program
Structure Proposal
The Conservation Program Structure
Proposal was finalized and issued June
28, 2005. It describes BPA’s approach to
offering conservation programs during
FY 2007 through FY 2009. The
decisions of this post-2006 proposal
were used as inputs in the development
of BPA’s WP–07 Power Rate Case Final
Proposal. BPA does not propose any
changes in this area for the WP–07
Supplemental Proceeding.
7. Transmission Rate Case
BPA is committed to marketing its
power and transmission services
separately in a manner modeled after
the regulatory initiatives adopted in
1996 by FERC to promote competition
in wholesale power markets. FERC’s
initiatives in Orders 888 2 and 889 3
directed public utilities regulated under
the Federal Power Act to separate their
power merchant functions from their
transmission reliability functions;
unbundle transmission and ancillary
services from wholesale power services;
and set separate rates for wholesale
generation, transmission, and ancillary
services. Although BPA is not required
by law to follow FERC’s regulatory
directives that promote competition and
open access transmission service, BPA
elected to separate its power and
transmission operations and unbundle
its rates in a manner consistent with the
directives concerning open access
transmission service. BPA develops its
transmission rates in separate
proceedings from its power rates.
On February 5, 2007, BPA’s
Transmission Services (formerly known
as the Transmission Business Line or
TBL) initiated a rate case to establish
transmission rates for the FY 2008–2009
transmission rate period. Prior to the
initiation of that rate case, Transmission
Services held several public meetings
with customers from July through
November 2006 to discuss transmission
costs, revenues, and rate design issues
for the FY 2008–2009 rate period.
Customers expressed interest in meeting
with Transmission Services to develop
a settlement for the FY 2008–2009 rate
period. Transmission Services
continued meetings with customers
between October and November 2006,
resulting in the 2008 Transmission Rate
Case Settlement Agreement.
On April 23, 2007, BPA issued the
‘‘Final Transmission Rate Proposal
Administrator’s Record of Decision’’
which adopted the transmission and
ancillary services rates reflected in the
2008 Transmission Rate Case Settlement
Agreement. FERC granted interim
approval to these rates on September 20,
2007. The Transmission Services rate
case settlement established fixed rates
for certain ancillary services and some
transmission rates that incorporate
ancillary services. The generation inputs
that support the ancillary services and
other control area services sold by
Transmission Services are provided by
Power Services. BPA is not proposing
any changes to its generation input costs
for FY 2009 except for the recognition
of additional revenues expected from
Transmission Services for Wind
Integration.
B. Scope of the WP–07 Supplemental
Proceeding
Many of the policies that guide BPA’s
power marketing decisions have been
made or will be made in other public
review processes. In addition, many
decisions about BPA’s financial
commitments, including for example,
what BPA plans to spend on meeting its
fish and wildlife obligations, are made
in forums other than the rate case. This
section provides guidance to the
Hearing Officer as to those matters that
are within the scope of the rate case,
and those that are outside the scope.
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this separate forum, BPA will provide
interested persons an opportunity to
review and comment on any
adjustments to program levels. After the
close of comment, BPA will issue a
closeout report detailing any necessary
adjustments to program levels. These
forecast costs will then be incorporated
into BPA’s final rate proposal for FY
2009.
2 Promoting Wholesale Competition Through
Open Access Non-Discriminatory Transmission
Services by Public Utilities; Recovery of Stranded
Costs by Public Utilities and Transmitting Utilities
Reg-Preamble, FERC Stats & Regs 1991–96, para.
31,036 (1996).
3 Open Access Same-Time Information System
(formerly Real-Time Information Networks) and
Standards of Conduct, Reg-Preamble, FERC Stats &
Regs 1991–96, para. 31,035 (1996).
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1. Program Level Expense Forecasts and
Commitments
Section 7(i) rate proceedings establish
the rates applicable to BPA’s products
and services at levels set to assure
recovery of BPA’s costs in total. The
section 7(i) proceeding does not
establish the program levels to be
recovered during a rate period. Instead,
program levels (including programmatic
decisions and decisions regarding
spending commitments) are decided in
various forums outside the section 7(i)
proceedings. Once set, however,
program levels are taken into
consideration when designing the rates
proposed in a section 7(i) proceeding to
ensure such costs are recovered. As
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described in Part II.A.5, BPA evaluated
whether updated forecasts of program
levels were needed for this WP–07
Supplemental Proceeding, and
determined that, except in a few
instances, they were not. Therefore,
except as noted above in Part II.A.5 and
described below, this WP–07
Supplemental Proceeding will not
revisit the previous forecasts of program
levels for FY 2007–2009 made in the
PFR I and II processes and incorporated
into the WP–07 Final Proposal. Nor is
this WP–07 Supplemental Proceeding
the forum to revisit or seek new
decisions regarding program spending
commitments for this period.
To allow public review and input on
program level forecasts that BPA has
determined require updating, BPA will
hold a separate process to address
adjustments to the program level
forecasts for FY 2009 associated with
CGS costs, fish and wildlife costs and
any other necessary program categories
for which significant changes have or
may occur before BPA’s final rate
proposal. This separate process will
include an opportunity for entities, such
as fish and wildlife managers, to engage
BPA on the cost assumptions made and
the appropriateness of any proposed
adjustments in forecasts. Any
adjustments adopted by BPA to the
program level forecasts for FY 2009 as
a result of this separate process will be
incorporated into BPA’s final rate
proposal for FY 2009. Because
discussions regarding spending
commitments or discussions about
adjustments in forecasts of costs in these
program areas will occur in forums
separate from this rate proceeding,
pursuant to § 1010.3(f) of BPA Hearing
Procedures, the Administrator hereby
directs the Hearing Officer to exclude
from the record any materials attempted
to be submitted or arguments attempted
to be made in the proceeding that seek
to address program spending
commitment decisions, or address
adjustments in the program level
forecasts for FY 2009 for CGS costs, fish
and wildlife costs, and any other
program categories.
2. Near-Term Policy Decisions
As detailed above, BPA issued the
Near-Term Policy on February 4, 2005.
The Policy resolved a number of policy
decisions that affect BPA’s WP–07
Supplemental Proposal. Those issues
include, but are not limited to, decisions
on the availability of the lowest cost PF
rate to public agency customers; the
term of the rate period; DSI service
options; and the availability of products
for new or existing customers. Pursuant
to § 1010.3(f) of the BPA Hearing
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Procedures, the Administrator hereby
directs the Hearing Officer to exclude
from the record any materials attempted
to be submitted or arguments attempted
to be made in the proceeding that seek
to in any way to revisit the
appropriateness or reasonableness of
BPA’s decisions made in the Near-Term
Policy ROD.
3. DSI Service
The DSI Service RODs established the
manner in which BPA would provide
service and benefits to its DSI customers
during FY 2007–2011. Pursuant to
§ 1010.3(f) of the BPA Hearing
Procedures, the Administrator directs
the Hearing Officer to exclude from the
record any materials attempted to be
submitted or arguments attempted to be
made in the proceeding that seek to in
any way to revisit the appropriateness
or reasonableness of BPA’s decisions
made in the DSI RODs.
4. Transmission Acquisition Expense
In the PFR I and II processes, BPA
reviewed with interested persons
program levels related to Power
Services’ transmission acquisitions.
These program levels represent the costs
associated with services necessary to
deliver energy from generating resources
to markets and loads. These costs
include: transmission expenses;
ancillary services; real power losses;
generation integration costs associated
with BPA-owned transmission facilities;
and metering and communication
requirements. Pursuant to § 1010.3(f) of
BPA Hearing Procedures, the
Administrator hereby directs the
Hearing Officer to exclude from the
record any materials attempted to be
submitted or arguments attempted to be
made in the hearing that seek to in any
way revisit the appropriateness or
reasonableness of BPA’s transmission
acquisition program level estimates.
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5. Other Transmission Issues
a. Generation Inputs
Power Services provides a portion of
the FCRPS’s available generation to
Transmission Services to enable
Transmission Services to meet its
various transmission and control area
requirements. Transmission Services
uses the generation inputs to provide
ancillary and control area services. To
recover the costs associated with
providing these generation inputs,
Power Services develops charges based
on relevant FCRPS costs that are
assessed the transmission function. The
costs Power Services are proposing to
use to determine the generation input
costs and associated unit costs to
Transmission Services were addressed
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in the BPA’s WP–07 Final Proposal.
Based on updated information, the WP–
07 Supplemental Proposal will include
revised charges for some generation
inputs and these revisions are included
within the scope of this rate proceeding.
Pursuant to § 1010.3(f) of BPA’s Hearing
Procedures, the Administrator directs
the Hearing Officer to exclude from the
record any materials attempted to be
submitted or arguments attempted to be
made in the proceeding that seek in any
way to revisit the appropriateness or
reasonableness of any issues, other than
the charges, related to the generation
inputs. This exclusion includes, but is
not limited to, issues regarding the level
or quality of the generation inputs that
Transmission Services requests from
Power Services. These determinations
are generally made by Transmission
Services in accordance with industry,
reliability, and other compliance
standards and criteria, and are not
matters appropriate for the WP–07
Supplemental Proceeding.
In addition, BPA will conduct a
section 7(i) process related to withinhour balancing capacity for wind
generation. Pursuant to § 1010.3(f) of
BPA’s Hearing Procedures, the
Administrator directs the Hearing
Officer to exclude from the record any
materials attempted to be submitted or
arguments attempted to be made in the
WP–07 Supplemental Proceeding that
seek in any way to address the issues
contained within the scope of the
within-hour balancing capacity for wind
generation rate proceeding (Proposed
Wind Integration—Within-Hour
Balancing Service Rate (WI–09)), except
that the appropriate treatment of the
additional revenue resulting from this
proceeding is a matter that is included
within the scope of the WP–07
Supplemental Proceeding.
b. Transmission Rate Case
On April 23, 2007, BPA issued the
2008 ‘‘Final Transmission ProposalAdministrator’s Record of Decision’’
that adopted the transmission and
ancillary services rates as reflected in
the 2008 Transmission Rate Case
Settlement Agreement. FERC granted
interim approval to these transmission
rates on September 20, 2007. Pursuant
to § 1010.3(f) of BPA Hearing
Procedures, the Administrator hereby
directs the Hearing Officer to exclude
from the record any materials attempted
to be submitted or arguments attempted
to be made in the hearing which seek in
any way to revisit the appropriateness
or reasonableness of issues determined
in the transmission rate case. That
proceeding addressed, among other
things, transmission and ancillary
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service rate levels, redispatch costs
between Transmission Services and
Power Services related to Attachment K
redispatch for FY 2008–2009, and the
level of the GTA Delivery Charge for FY
2009.
6. Post-2006 Conservation Program
Structure Proposal
Through the post-2006 workgroup
collaboration, customers and
constituents provided input on the
development of BPA’s post-2006
conservation approach. Pursuant to
§ 1010.3(f) of BPA Hearing Procedures,
the Administrator hereby directs the
Hearing Officer to exclude from the
record any materials attempted to be
submitted or arguments attempted to be
made in the hearing that seek to in any
way revisit the appropriateness or
reasonableness of BPA’s conservation
programs and establishment of their
associated expense levels through the
Post-2006 Conservation Program
Structure Proposal dated June 28, 2005.
The Hearing Officer is also directed to
exclude from the scope of this
proceeding evidence regarding BPA’s
portfolio of conservation programs, as
well as their expenses, that BPA intends
to pursue during FY 2009.
7. Federal and Non-Federal Debt Service
and Debt Management
During the PFR, and in other forums,
BPA has provided background
information on its internal Federal and
non-Federal debt management policies
and practices. The discussions of these
topics in the PFR and other forums were
not intended to seek input from
customers and constituents regarding
BPA’s debt management policies and
practices. Rather, these discussions
were intended to merely inform
interested parties about these matters so
that they would better understand
BPA’s debt structure. Although the PFR
closeout letter did not make any
decisions regarding BPA’s debt
management policies and practices,
these remain outside the scope of the
rate case. Therefore, pursuant to
§ 1010.3(f) of BPA Hearing Procedures,
the Administrator hereby directs the
Hearing Officer to exclude from the
record any materials attempted to be
submitted or arguments attempted to be
made in the hearing which seek to in
any way visit the appropriateness or
reasonableness of BPA’s debt
management policies and practices.
8. Average System Cost Methodology
Concurrent with the publication of
this notice, BPA is publishing a separate
notice in the Federal Register to
commence a consultation proceeding to
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develop a new Average System Cost
(ASC) Methodology. Section 5(c) of the
Northwest Power Act established the
REP, which provides benefits to
residential consumers of Pacific
Northwest utilities based, in part, on a
utility’s ‘‘average system cost’’ of
resources. Section 5(c)(7) of the Act
authorizes the Administrator to consult
with regional interests to develop an
ASC methodology. The ASC
Methodology prescribes which costs are
included and excluded from a utility’s
ASC, as well as the procedural rules for
filing proposed ASCs with BPA.
Comments on BPA’s proposed ASC
Methodology will be submitted,
reviewed and addressed solely in the
separate consultation proceeding. For
this reason, issues related to the
proposed ASC Methodology are not
within the scope of this proceeding.
Therefore, pursuant to § 1010.3(f) of
BPA Hearing Procedures, the
Administrator hereby directs the
Hearing Officer to exclude from the
record any materials attempted to be
submitted or arguments attempted to be
made in the hearing that seek to in any
way visit the appropriateness or
reasonableness of the proposed ASC
Methodology.
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9. Potential Environmental Impacts
For the reasons stated in Section C
below, the Administrator directs the
Hearing Officer to exclude from the
record all evidence and arguments that
seek in any way to address the potential
environmental impacts of the rates
being developed in the WP–07
Supplemental Proceeding. Any such
evidence and arguments submitted will
be considered and addressed in the
separate, concurrent process described
in the next section.
C. The National Environmental Policy
Act
BPA is in the process of assessing the
potential environmental effects of its
WP–07 Supplemental Proposal,
consistent with the National
Environmental Policy Act (NEPA).
BPA’s Business Plan Environmental
Impact Statement (Business Plan EIS),
completed in June 1995, evaluated the
environmental impacts of a range of
business plan alternatives that could be
varied by applying 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 addressed response
strategies, including adjusting rates, that
BPA could pursue if BPA’s costs
exceeded its revenues. In August 1995,
the BPA Administrator issued a Record
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of Decision (Business Plan ROD) that
adopted the Market-Driven 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
Supplemental Analysis to the Business
Plan EIS. The Supplemental Analysis
found that the Business Plan EIS’s
relationship-based and policy-level
analysis of potential environmental
impacts from BPA’s business practices
remains valid, and that BPA’s current
business practices are still consistent
with BPA’s Market-Driven 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.
Because the WP–07 Supplemental
Proposal 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 significantly
different environmental impacts from
those examined in the Business Plan
EIS. Therefore, BPA expects that this
WP–07 Supplemental Proposal will 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
Supplemental ROD that will be
prepared for the FY 2007 Supplemental
Wholesale Power Rate Proposal, 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. During the public review and
comment period for the WP–07
Supplemental Proposal, persons
interested in submitting comments
regarding its potential environmental
effects may do so by submitting
comments 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
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7545
deadline identified in Part I will be
considered by BPA’s NEPA compliance
staff in the NEPA process that will be
conducted for this Proposal.
Part III—Public Participation
A. Distinguishing Between
‘‘Participants’’ and ‘‘Parties’’
BPA distinguishes between
‘‘participants in’’ and ‘‘parties to’’ the
section 7(i) hearing process. Apart from
the formal hearing process, BPA will
accept comments, views, opinions, and
information from ‘‘participants,’’ who
are defined in the BPA Hearing
Procedures as persons who may submit
comments without being subject to the
duties of, or having the privileges of,
parties. Participants’ written and oral
comments will be made a part of the
official record and considered by the
Administrator when making his
decision. 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.
The views of participants are
important to BPA. Written comments by
participants will be included in the
record if they are received by 5:00 p.m.,
Pacific Daylight Savings Time, on May
5, 2008. This date follows the
anticipated submission of BPA’s and all
other parties’ direct cases. Written
views, supporting information,
questions, and arguments should be
submitted to BPA Public Affairs at the
address listed in Paragraph 2 of the
Summary. In addition, BPA will hold
two field hearings in the Pacific
Northwest region. Participants may
appear at the field hearings and present
verbal and written comments. The
transcripts of these hearings will be part
of the record upon which the
Administrator makes his final rate
decisions.
Persons who previously intervened in
BPA’s 2007 Wholesale Power Rate
Adjustment Proceeding automatically
continue their party status in the 2007
Supplemental Proceeding. Other
persons wishing to become a party to
BPA’s rate proceeding must notify BPA
in writing and file a Petition to
Intervene with the Hearing Officer.
Petitioners may designate no more than
two representatives upon whom service
of documents will be made. Petitions to
Intervene must state the name and
address of the person requesting party
status and the person’s interest in the
hearing.
Petitions to Intervene as parties in the
rate proceeding are due to the Hearing
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Officer by 5 p.m., Pacific Standard
Time, on February 18, 2008. The
petitions should be directed as stated
below or may be e-mailed to
wp07rate@bpa.gov: Robert Welsh,
Hearing Clerk–LP–7, Bonneville Power
Administration, 905 NE 11th Avenue,
P.O. Box 3621, Portland, OR 97208–
3621.
Petitioners must explain their
interests in sufficient detail to permit
the Hearing Officer to determine
whether they have a relevant interest in
the proceeding. Pursuant to § 1010.1(d)
of BPA Hearing Procedures, BPA waives
the requirement in § 1010.4(d) that an
opposition to an intervention petition
must be filed and served 24 hours before
the February 19, 2008, prehearing
conference. Any opposition to an
intervention petition may instead be
made at the prehearing conference. Any
party, including BPA, may oppose a
petition for intervention. Persons who
have been denied party status in any
past BPA rate proceeding shall continue
to be denied party status unless they
establish a significant change of
circumstances. All timely applications
will be ruled on by the Hearing Officer.
Late interventions are strongly
disfavored.
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B. Developing the Record
The record will comprise, among
other things, verbal and written
comments made by participants,
including the transcripts of all hearings,
any written materials submitted by the
parties, documents developed by BPA
staff, and other materials accepted into
the record by the Hearing Officer.
Written comments by participants will
be included in the record if they are
received by 5 p.m., Pacific Daylight
Savings Time, on May 5, 2008. The
Hearing Officer will then review the
record, supplement it if necessary, and
will certify the record to the
Administrator for decision.
The Administrator will develop final
proposed rates for FY 2009 based on the
entire record, which includes the record
certified by the Hearing Officer, as
described above. The basis for the final
proposed rates first will be expressed in
the Administrator’s Draft Supplemental
ROD. Parties will have an opportunity
to respond to the Draft Supplemental
ROD as provided in the BPA Hearing
Procedures. The Administrator will
serve copies of the Final Supplemental
ROD on all parties. At the conclusion of
the rate proceeding, BPA will file the
supplemental rate case record and rates
for FY 2009 in a timely manner to
receive FERC confirmation and approval
effective October 1, 2008.
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BPA must continue to meet with
customers in the ordinary course of
business during the rate case. To
comport with the rate case procedural
rule prohibiting ex parte
communications, BPA will provide the
prescribed notice of meetings involving
rate case issues in order to permit the
opportunity for participation by all rate
case parties. These meetings may be
held on very short notice. Consequently,
parties should be prepared to devote the
necessary resources to participate fully
in every aspect of the rate proceeding
and attend meetings any day during the
course of the rate case.
Part IV—Summary of WP–07
Supplemental Proposal and Major
Studies
A. Summary of Proposed 2009
Wholesale Power Rate Structure
1. List of Proposed 2009 Wholesale
Power Rates
BPA is proposing to revise several rate
schedules for its 2007 Supplemental
Wholesale Power Rates to respond to
the Court’s recent opinions. The rate
schedules and the GRSPs are available
for viewing and downloading on BPA’s
Web site at https://www.bpa.gov/
corporate/ratecase as discussed in Part
VII of this Notice.
a. PF–07R Priority Firm Power Rate
The PF rate schedule is comprised of
two rates: the PF Preference rate and the
PF Exchange rate.
The PF Preference rate applies to
BPA’s firm power sales to public bodies,
cooperatives, and Federal agencies for
resale to their regional consumers. This
power is guaranteed to be continuously
available. The proposed average PF
Preference rate is $26.2/MWh. The rate
applies to the following products:
Full Service Product
Actual Partial Service Product—Simple
Actual Partial Service Product—
Complex
Block Product
Block Product with Factoring
Block Product with Shaping Capacity
Slice Product
The PF Exchange rate applies to sales
of power to regional utilities that
participate in the Residential Exchange
Program established under section 5(c)
of the Northwest Power Act. 16 U.S.C.
839c(c). BPA is proposing to revise the
PF Exchange rate to remove the demand
and energy rates and substitute a single
annual rate. In addition, BPA is
proposing to include utility-specific
supplemental rate charges, consistent
with section 7(b)(3) of the Northwest
Power Act. 16 U.S.C. 839e(b)(3). These
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PF Exchange rates are used in
determining REP benefits in FY 2009.
b. NR–07R New Resource Firm Power
Rate
The New Resource Firm Power (NR)
rate applies to net requirements power
sales to IOUs for resale to ultimate
consumers for direct consumption,
construction, test and start-up, and for
station service. NR–07R firm power is
also available to public utility customers
for serving New Large Single Loads.
This rate applies to the following
products:
New Large Single Loads
Full Service Product
Actual Partial Service Product—Simple
Actual Partial Service Product—
Complex
Block Product
Block Product with Factoring
Block Product with Shaping Capacity
c. IP–07R Industrial Firm Power Rate
The IP rate is available for
discretionary 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).
d. FPS–07R Firm Power Products and
Services Rate
The FPS rate schedule is available for
the purchase of Firm Power, Capacity
Without Energy, Supplemental Control
Area Services, Shaping Services, and
Reservation and Rights to Change
Services for use inside and outside the
Pacific Northwest. The rates for these
products are posted and/or negotiated.
BPA is proposing only minor changes to
this rate schedule for FY 2009.
e. GTA–07R General Transfer
Agreement Delivery Charge
The GTA Delivery Charge applies to
customers who purchase Federal power
that is delivered over non-Federal low
voltage transmission facilities. This rate
was originally set in the 2006
Transmission Services Rate Case
Settlement to mirror the Utility Delivery
rate from October 1, 2005, through
September 30, 2007. BPA’s 2007 Power
Rate Case determined that the GTA
Delivery Charge would continue to
mirror the Utility Delivery rate, which is
$1.119 per kilowatt through September
30, 2009. For FY 2009, Power Services
is proposing to continue to set the GTA
Delivery Charge to the same rate as
Transmission Services’ posted monthly
Utility Delivery rate, which is $1.119
per kilowatt.
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2. Significant Rate Development Issues
a. Residential Exchange Program Costs
For FY 2009, BPA expects qualifying
regional utilities to participate in the
REP. BPA is concurrently developing a
new ASC Methodology in a separate
proceeding and will be offering new
RPSAs to requesting utilities. In order to
include the costs of an REP in BPA’s FY
2009 rates, BPA is forecasting the ASCs
of utilities expected to participate in the
program. In addition, BPA is forecasting
the expected utilities’ system and
exchangeable residential and small farm
loads. However, the ASC Methodology
being revised in a concurrent process
will be used to conduct an expedited
review of utilities’ ASCs outside of this
WP–07 Supplemental Proceeding. This
review will determine the actual ASCs
for eligible utilities for FY 2009. Those
ASC determinations, when complete,
will be incorporated into the final rate
proposal and used to determine REP
costs in FY 2009 rates.
b. Inter-Function Costs and Credits
BPA is not proposing any changes to
its inter-function generation input unit
charges for FY 2009. The forecast of
revenues for FY 2009 in the WP–07
Final Proposal will continue to be used.
However, BPA will adjust the interfunction revenue credit to reflect the
additional revenues that Power Services
expects to receive from Transmission
Services based on the proposed Wind
Integration—Within-Hour Balancing
Service Rate Proceeding (WI–09).
Therefore, BPA is proposing to
incorporate the forecast revenues
determined in the Wind Integration rate
case into the final rates of this
proceeding.
c. DSI Service FY 2007–2011
BPA continues to forecast no direct
service sales under the IP rate to its DSI
customers. Instead, BPA provides the
DSI aluminum smelters 560 aMW of
surplus firm power service benefits for
the FY 2007–2011 period at a capped
cost of $59 million per year. Benefits
have been monetized under the contacts
with these companies. In addition, BPA
provides a 17 aMW surplus firm power
sales contract for Port Townsend Paper
Company through the local public
utility under the FPS rate schedule at a
rate that is approximately equivalent to
BPA’s lowest-cost PF rate.
3. Rate Design and Rate Adjustments
Consistent with the Partial Resolution
of Issues negotiated between BPA and
rate case parties before the WP–07 Final
Proposal, BPA is generally continuing
its existing WP–07 rate design for its FY
2009 rates, with only minor
modifications listed below. In addition,
BPA is generally continuing its existing
set of rate adjustments for its FY 2009
rates, also described below.
a. Conservation Rate Credit (CRC)
BPA is not proposing any changes
from its WP–07 Final Proposal for the
CRC.
b. Risk Mitigation Tools
Other than resetting the cap for the FY
2009 Cost Recovery Adjustment Clause
(CRAC) and the thresholds for the FY
2009 CRAC and Dividend Distribution
Clause (DDC), BPA is proposing no
other changes to the CRAC or DDC in
the WP–07 Supplemental Proposal. BPA
will use the same technical
methodology to assess risks and intends
to employ the same risk mitigation
measures as presented in the WP–07
Final 4 Proposal.
TABLE 1.—CRAC CAP AND CRAC AND DDC ANNUAL THRESHOLDS FOR FY 2009
[Millions of dollars]
AMNR calculated at end
of fiscal year
CRAC or DDC
applied to
fiscal year
CRAC or DDC
threshold in
AMNR 4
Approx.
threshold as
measured in
power services’ reserves
2008
2008
2009
2009
($81.4)
218.6
$750
1,050
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CRAC .................................................................................
DDC ...................................................................................
BPA proposes to continue the
National Marine Fisheries Service
(NMFS) Federal FCRPS Biological
Opinion (NFB) Adjustment and the
Emergency NFB Surcharge. Although
BPA expects to include the forecast cost
of implementing the final Biological
Opinion for the FCRPS in its final
supplemental rates, litigation regarding
the Biological Opinion may continue, so
the Emergency NFB Surcharge and the
NFB Adjustment remain appropriate. In
order to balance the need to cover risk
with overall rate levels, BPA proposes to
meet its Treasury Payment Probability
(TPP) standard through a combination
of financial reserves, the CRAC, the NFB
Adjustment, the Emergency NFB
Surcharge, and the Flexible PF Rate
Program. See Part IV.A.4.
4 Accumulated
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c. Excess Factoring Charge
This is a charge that applies to
purchasers of the Complex Actual
Partial Service Product under the PF
rate schedule. BPA is proposing no
changes to this charge as established in
the WP–07 Final Proposal.
d. Green Energy Premium (GEP)
BPA is proposing no changes to the
GEP in this Supplemental Proposal. The
proposed GEP continues to range from
zero to 40 mills per kWh depending on
the specific products and associated
costs selected by each customer. BPA
forecasts an average of $3 million of
annual revenue from the GEP for FY
2009, which is an increase from the
WP–07 Final Proposal. A portion of
revenues from the GEP will support
BPA’s renewable-related research,
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$36
n/a
development and demonstration
projects.
e. Load Variance Charge
Except for a change in its level,
consistent with the Partial Resolution of
Issues, BPA is proposing no other
changes to the Load Variance Charge.
This proposed charge of $0.45/MWh
covers BPA’s cost of meeting customers’
load growth for reasons other than
annexation or retail access load gain or
loss. In addition, it provides Full and
Partial Service purchasers the right to
deviate from their monthly forecast of
BPA purchases due to weather,
economic business cycles, plant energy
consumptions and other reasons.
f. Low Density Discount (LDD)
BPA is proposing no changes to the
LDD as established in the WP–07 Final
Modified Net Revenue
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Maximum
CRAC recovery amount
(cap)
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Proposal and as agreed to in the Partial
Resolution of Issues.
g. Monthly Demand and Energy Charges
BPA is proposing no changes to the
methodology for calculating demand
and energy charges. There will be two
diurnal periods, Heavy Load Hour
(HLH) and Light Load Hours (LLH), for
each month. BPA continues to adopt
slight changes to the definitions of HLH
and LLH to be consistent with NERC
definitions. The proposed demand and
energy charges will be updated
consistent with the Partial Resolution of
Issues.
h. PF Targeted Adjustment Charge (PF
TAC)
BPA is proposing no changes to the
Targeted Adjustment Charge from that
established in the WP–07 Final
Proposal.
i. Unauthorized Increase Charges (UAI)
for Power Sales
These are penalty charges for
Unauthorized Increases in Energy and
Unauthorized Increases in Demand for
deliveries that exceed contractual
entitlements for energy and demand,
respectively. BPA is proposing no
changes relative to the WP–07 Final
Proposal.
j. Demand Adjuster
This is an adjustment that is made to
the demand billing factor for certain
requirements products. BPA is
proposing no changes relative to the
WP–07 Final Proposal.
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k. Flexible PF and NR
These are rate options available, at
BPA’s discretion, to purchasers under
the PF and NR rate schedules. BPA is
proposing no changes relative to the
WP–07 Final Proposal.
l. Slice True-Up Adjustment
BPA is proposing changes to the Slice
True-up Adjustment process that are
consistent with the (Slice Mediation)
Settlement Agreement that was signed
after the WP–07 Final Proposal was
published. This Settlement Agreement
provided for the Slice True-Up
Adjustment Charge to be calculated
using the average Slice Revenue
Requirement for the rate period instead
of the Slice Revenue Requirement for
each individual year. In addition, this
Settlement Agreement provided for
changes in the treatment of certain
expenses, which are incorporated in this
proposal.
m. Value of Reserves
Section 7(c)(3) of the Northwest
Power Act, 16 U.S.C. 839e(c)(3),
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provides that the Administrator shall
adjust rates to the DSI customers ‘‘to
take into account the value of power
system reserves made available to the
Administrator through his rights to
interrupt or curtail service to such direct
service industrial customers.’’ The DSIs
may provide two types of reserves:
Supplemental Contingency Reserves
and Stability Reserves. The WP–07
Supplemental Proposal reflects Stability
Reserves being purchased by
Transmission Services and addressed in
Transmission Services’ transmission
rate case. BPA is proposing no changes
relative to the WP–07 Final Proposal.
n. Development of IP and NR Rates
Other than the level of the rates, BPA
is proposing no changes to the NR or IP
rates relative to the WP–07 Final
Proposal.
4. Rate Methodology for FY 2009
a. Risk Mitigation Package
Power Services is proposing to rely on
a number of elements for its risk
mitigation package in the WP–07
Supplemental Proposal. These include a
CRAC, with the NFB Adjustment and
Emergency NFB Surcharge, and a DDC,
as well as the following:
(1) Starting Reserves Available for
Risk. The financial reserves available for
risk that are attributable to Power
Services at the start of the rate period
provide some protection against
financial uncertainties. Starting
financial reserves available for risk
include portions attributed to the
generation function of cash in the BPA
Fund and the deferred borrowing
balance that are attributed to the
generation function. Projections of
Power Services’ reserves available for
risk at the beginning of FY 2009 range
from $50 million to $2.7 billion, with an
expected value of $1.03 billion. These
amounts do not include cash that has
accumulated as a result of the
suspension of payments under the REP
Settlement Agreements.
(2) Planned Net Revenues for Risk
(PNRR). PNRR is a dollar amount in the
generation revenue requirement that
generates additional revenue in order to
increase the generation function
reserves. The anticipated generation
function reserves available for risk, with
the tools noted above, are sufficient for
the agency to meet its financial objective
of a 97.5 percent one-year TPP for FY
2009. As a result, BPA’s proposed risk
mitigation package will not include any
PNRR.
(3) Flexible PF Rate Program. This
program is designed to provide $193
million of liquidity cash through an
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accelerated payment of certain
participating public utilities’ power
bills. This accelerated payment will be
triggered at BPA’s sole discretion should
the probability of reserves falling below
a certain reserve threshold be greater
than the acceptable probability, as
decided prior to a cash crisis.
b. Rates Analysis Model (RAM)
The RAM2009 model is a large Excel
spreadsheet model that is automated
with Visual Basic macros. RAM2009 has
two main steps: a Rate Design Step and
a Slice Separation Step. The RAM2009
Rate Design Step implements BPA’s rate
directives by modifying the costs
associated with the three resource pools
(Federal Base System, Residential
Exchange, and New Resources) used to
serve three rate pools (7(b) loads, 7(c)
loads, and 7(f) and surplus loads) as
developed in the Cost of Service
Analysis (COSA). After the initial
allocation of costs, the Northwest Power
Act requires that some rate adjustments
be made, such as those described in
section 7(b) and section 7(c) of the
Northwest Power Act. The RAM2009
performs these rate adjustments, and
several others, including the 7(b)(2) rate
test, in its Rate Design Step. The Rate
Design Step of RAM2009 concludes
with the calculation of proposed power
rates. The Slice Separation Step then
separates the PF Slice product costs and
firm loads from the overall PF
Preference rate pool, leaving the costs
that must be covered by the remaining
non-Slice product PF Preference load.
B. Major Studies in Support of WP–07
Supplemental Proposal for FY 2009
Rates
Because this proceeding reopens the
WP–07 docket, all material already filed
on the record remains on the record and
is available to all parties. BPA’s WP–07
Final Proposal Studies constitute the
foundation on which the Supplemental
Proposal is built. However, certain new
information will be incorporated to form
the Supplemental Proposal. BPA will
explain and document the revisions that
are incorporated in the Supplemental
Proposal in a new set of studies. The
studies that have been prepared to
support BPA’s WP–07 Supplemental
Wholesale Power Rate Proposal are
described in detail in this section:
Supplemental Load Resource Study
and Documentation;
Supplemental Revenue Requirement
Study and Documentation;
Supplemental Market Price Forecast
Study and Documentation;
Supplemental Risk Analysis Study
and Documentation;
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Supplemental Wholesale Power Rate
Development Study and
Documentation;
Supplemental Section 7(b)(2) Rate
Test Study and Documentation; and
Lookback Study and Documentation
for FY 2002–2008.
changes in Federal resource output for
FY 2009 resulting from recent BPA
acquisitions and contract purchases,
updated assumptions for the CGS
maintenance schedule, and revisions to
BPA’s hydro efficiency improvement
estimates.
1. Supplemental Load Resource Study
The Load Resource Study represents
the compilation of the load and resource
data necessary for developing BPA’s
wholesale power rates. The Study has
three major interrelated components: (a)
BPA’s Federal system load forecast; (b)
BPA’s Federal system resource forecast;
and (c) the Federal system load and
resource balances.
Since publication of the WP–07 Final
Proposal, only a few minor changes
have occurred. The Supplemental Load
Resource Study documents the increase
in load BPA is currently forecasting for
FY 2009 relative to the WP–07 Final
Proposal. It also recognizes some
2. Supplemental Revenue Requirement
Study
The purpose of the Revenue
Requirement Study is to establish the
level of revenues from wholesale 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.
Generation revenue requirements
include: Recovery of the Federal
investments in hydro generation;
recovery of fish and wildlife costs and
energy conservation; Federal agencies’
operations and maintenance expenses
allocated to power; capitalized contract
7549
expenses associated with such nonFederal power suppliers as Energy
Northwest; other purchase power
expenses, such as short-term power
purchases; power marketing expenses;
cost of transmission services necessary
for the sale and delivery of FCRPS
power; and all other power-related costs
incurred by the Administrator pursuant
to law.
For FY 2009, BPA is forecasting that
most power-related costs will remain at
the same levels as in the WP–07 Final
Proposal, with the exception of the costs
associated with the REP. A limited
number of additional changes is
proposed for the Supplemental
Proposal. Forecasts of operating costs
for the CGS show an increase as do the
costs related to system augmentation.
Depreciation, amortization, Federal
interest and non-Federal debt service
will be updated. The proposed changes
are presented in Table 2.
TABLE 2.—DIFFERENCES IN MAJOR COST CATEGORIES BETWEEN THE WP–07 FINAL PROPOSAL AND THE WP–07
SUPPLEMENTAL PROPOSAL FY 2009 (EXCLUDING REP COST CHANGES)
[Millions of dollars]
Changes from
WP–07 final proposal
Cost category
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Operating Generation:
CGS ..........................................................................................................................................................................................
Long-term Projects ...................................................................................................................................................................
Contracted Power Purchases:
DSI Monetized Power Sale ......................................................................................................................................................
Other Power Purchases (Short-term) .......................................................................................................................................
Augmentation Power Purchases .....................................................................................................................................................
Renewable Generation ....................................................................................................................................................................
Energy Efficiency .............................................................................................................................................................................
Transmission Acquisition/Ancillary Services ...................................................................................................................................
EN Debt Service ..............................................................................................................................................................................
Depreciation .....................................................................................................................................................................................
Amortization .....................................................................................................................................................................................
Net Federal Interest .........................................................................................................................................................................
Minimum Required Net Revenues ..................................................................................................................................................
Planned Net Revenues for Risk ......................................................................................................................................................
Total Change from WP–07 Final Proposal .....................................................................................................................................
BPA also expects changes to the costs
of its fish and wildlife commitments,
particularly from the final FCRPS
Biological Opinion, now expected on
March 18, 2008. For reasons of
efficiency and to ensure the most up-todate information, BPA prefers to
estimate those changes when the
Biological Opinion is issued. If the
Opinion is delayed, BPA will forecast
those costs using the best available
information. As noted above, BPA does
not establish program levels in rate
cases. BPA will conduct a review of
changes to the power-related costs from
the WP–07 Final Proposal in a forum
external to this proceeding. The results
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17:11 Feb 07, 2008
Jkt 214001
of that review will be incorporated into
the final studies of this WP–07
Supplemental Proceeding.
3. Supplemental Market Price Forecast
Study
The Market Price Forecast Study
estimates the variable hourly cost of the
marginal resource for transactions in the
wholesale energy market. The specific
market used in this analysis is the MidColumbia trading hub in the State of
Washington. For the WP–07
Supplemental Proposal, BPA does not
propose to change the price forecast
from the WP–07 Final Proposal.
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31
6
(4)
11
17
11
9
(5)
1
(7)
(8)
(27)
(35)
(11)
(10)
4. Supplemental Risk Analysis Study
The Risk Analysis Study focuses upon
two types of risks and their impacts on
BPA’s revenues and expenses. The first
type of risks is comprised of operating
risks such as variations in economic
conditions, load, and generation
resource capability. These operating
risks include the impacts of water
supply conditions and market prices on
net revenues. The second type of risks
comprises non-operating risks—all the
risks included in the rate case risk
modeling other than operating risks.
This type of non-operating risks also
includes uncertainty in achieving cost
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reductions identified in the Power
Function Review.
BPA subsequently evaluates the
impact that different risk mitigation
measures have on reducing net revenue
risk by calculating the TPP. The TPP is
a measure of the probability that BPA
will make each Treasury payment on
time and in full. If the TPP is below
BPA’s one-year 97.5 percent standard,
the combination of risk mitigation tools
(e.g., Cost Recovery Adjustment Clause,
NFB Adjustment, Emergency NFB
Surcharge, Dividend Distribution
Clause) is modified to meet the TPP
standard.
BPA is proposing no changes in the
form or methodology of the risk
analysis. The Supplemental Proposal
risk analysis will be updated for
changes to input data that account for
changes in BPA’s loads, resources, costs,
and financial position.
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5. Supplemental Wholesale Power Rate
Development Study
The Wholesale Power Rate
Development Study (WPRDS) is the
primary source for details concerning
the development of BPA’s power rates.
It reflects the results of all of the other
studies and calculates the rates for
BPA’s wholesale power products and
services. The WPRDS documents the
allocation and recovery of Federal
power costs; development of the Slice
cost table; the development and forecast
of inter-function revenues and expenses;
the development of diurnal energy rates;
the development of rates for demand,
load variance, unauthorized increase
usage, and excess load factoring; and
other rate provisions (e.g., the Low
Density Discount, Conservation Rate
Credit, and irrigation rate mitigation).
The results of the WPRDS are reflected
in the wholesale power rate schedules.
Because of the Ninth Circuit’s
decisions on the allocation of the costs
of the REP Settlement Agreements, most
of the changes in the Supplemental
Proposal are focused on the WPRDS.
With the exception of certain auxiliary
rate provisions, the WPRDS will be
reproduced to document fully the
development of BPA’s power rates for
the WP–07 Supplemental Proposal.
6. Supplemental Section 7(b)(2) Rate
Test Study
The 7(b)(2) rate test is explained
below in Part V. The Section 7(b)(2)
Rate Test Study describes the
application and results of the Section
7(b)(2) Legal Interpretation (Legal
Interpretation) and Section 7(b)(2)
Implementation Methodology
(Implementation Methodology). BPA is
proposing revisions to the Legal
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Interpretation and Implementation
Methodology in the WP–07
Supplemental Proceeding. See Part V
below.
The 7(b)(2) rate test triggers in this
proposal, causing costs to be reallocated
in the test period. The PF Preference
rate applied to the general requirements
of the 7(b)(2) Customers has been
reduced by the 7(b)(3) amount. Other
rates, the PF Exchange rate and the NR
and IP rates, have been increased by an
allocation of the 7(b)(3) amount.
Because of the proposed changes to
the Legal Interpretation and
Implementation Methodology, the
Section 7(b)(2) Rate Test Study is being
fully reproduced to document the
changes to the rate test and its inputs
and assumptions.
7. Lookback Study for FY 2002–2008
The Lookback Study for FY 2002–
2008 quantifies the amounts of REP
settlement costs improperly included in
FY 2002–2008 power rates (Lookback
Amounts) and describes how these
amounts will be recovered over time
from IOUs and returned to preference
customers. These are not simple
calculations for each year of the
lookback period because of the need to
account for Load Reduction Agreements
and existing deemer balances. See Part
VI.D. The differences are referred to as
Lookback Amounts for FY 2002–2008.
The calculation of Lookback Amounts is
described and documented in the
Lookback Study.
Part V—Section 7(b)(2) Legal
Interpretation and Implementation
Methodology
A. Background
As explained above, section 7(b)(2) of
the Northwest Power Act directs BPA to
conduct a rate test to assure that the
wholesale power rates for 7(b)(2)
customers are no higher than the costs
of power would be to those customers
for the same time period if specified
assumptions are made. The rate test is
conducted in conformance with the
Section 7(b)(2) Legal Interpretation and
Section 7(b)(2) Implementation
Methodology.
Issues requiring interpretation of
Section 7(b)(2) of the Northwest Power
Act were initially resolved in the Legal
Interpretation of Section 7(b)(2) of the
Pacific Northwest Electric Power
Planning and Conservation Act. 49 FR
23,998 (June 8, 1984). The Legal
Interpretation was developed in a
public comment process.
The methodology to implement
section 7(b)(2) was developed in a
section 7(i) proceeding that preceded
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BPA’s 1985 rate case. The 7(i) process
culminated in the Section 7(b)(2)
Implementation Methodology Record of
Decision (b–2–84–F–02). The 7(i)
process conducted to develop the
Implementation Methodology for
section 7(b)(2) was designated as the
first phase of BPA’s 1985 rate filing. The
Implementation Methodology prescribes
in detail how the 7(b)(2) rate test is to
be conducted. The Implementation
Methodology and its ROD address the
major issues involving the
implementation of section 7(b)(2),
including reserve benefits, financing
benefits, natural consequences, and the
rate test trigger.
BPA is proposing revisions to the
Implementation Methodology and the
Legal Interpretation in the WP–07
Supplemental Proposal. Proposed
changes to the Implementation
Methodology will be explained in BPA’s
Supplemental Proposal testimony.
Proposed changes to the Legal
Interpretation are contained in the Legal
Interpretation attached to this Notice.
Legal arguments concerning the Legal
Interpretation will be addressed by BPA
in the WP–07 Supplemental Proposal
Draft and Final Records of Decision.
BPA expects parties to have the
opportunity to file legal briefs or
memoranda to accompany and support
their rate test testimonies in order that
their legal arguments can be reviewed
by BPA prior to receiving the parties’
initial briefs.
In preparing for the WP–07
Supplemental Proceeding, BPA and
interested parties explored various
issues regarding the Legal Interpretation
and Implementation Methodology
through several workshops. In order to
bring greater clarity and certainty to the
conduct of the rate test, BPA is
proposing a number of modifications to
the Legal Interpretation and
Implementation Methodology. The
major modifications are listed below.
A. Treatment of Preference Customer
Resources Used To Serve Requirements
Loads
The current Legal Interpretation and
Implementation Methodology provide
that preference customers’ resources
dedicated to serving their own firm
loads under section 5(b) of the
Northwest Power Act are not available
to BPA in the 7(b)(2)(D) resource stack
to serve 7(b)(2) Customer load. BPA
proposes to clarify its interpretation of
section 7(b)(2)(D) to provide that
preference customer resources that are
used to serve any utility’s section 5(b)
load are not available in the 7(b)(2) Case
resource stack.
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B. Treatment of BPA-Acquired
Conservation
excluded from the 7(b)(2) Case pursuant
to section 7(b)(2)(C).
The current Implementation
Methodology provides that BPAacquired conservation will be included
in the section 7(b)(2)(D) resource stack
and that 7(b)(2) Customer loads will be
adjusted to remove the effects of the
conservation. The Implementation
Methodology made no provision for
conservation that is no longer effective
in reducing loads. BPA is proposing to
revise the Methodology to remove past
conservation that is no longer effective.
Part VI. Summary of Proposal to
Respond To the Court’s Opinions
Regarding BPA’s 2000 REP Settlement
Agreements, WP–02 Rates, and by
Extension, WP–07 Rates
C. Identification and Use of Natural
Consequences
The current Legal Interpretation and
Implementation Methodology provide
that three natural consequences will be
reflected in the rate test: demand
elasticities amount of surplus firm
power available, and size of nonfirm
energy markets. The surplus and
nonfirm consequences are the results of
reasonable mathematical computations
stemming from differing assumptions
between the two rate test cases. Demand
elasticities are not necessarily the result
of reasonable mathematical
computations. BPA is proposing to
remove demand elasticities from the
natural consequences listed in the
Implementation Methodology.
D. Treatment of Specified 7(g) Costs
The current Legal Interpretation
provides that specified 7(g) costs will be
removed from the Program Case, but not
from the 7(b)(2) Case. However, this
language does not conform to BPA’s
past practices in conducting the rate
test. BPA proposes to change this
language to specify that the 7(g) cost
exclusion applies to both cases prior to
the incorporation of the assumptions
specified in section 7(b)(2).
E. Identification and Treatment of
Resources in the 7(b)(2)(D) Resource
Stack
The current Implementation
Methodology provides that certain
resources taken from the resource stack
would be added in discrete lumps. BPA
proposes to remove the effects of the
discrete lumps on the rate test by selling
excess resources at the cost of the excess
resources.
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F. Treatment of REP Settlement Costs in
the Rate Test
Neither the current Legal
Interpretation nor Implementation
Methodology addresses the treatment of
REP settlement costs. BPA proposes to
add language that clarifies that REP
settlement costs are costs that should be
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A. Introduction
Although BPA is proposing an
approach to address the Court’s
decisions, as described in greater detail
below, BPA recognizes there are several
ways to approach this matter. For
example, one element of BPA’s proposal
for calculating the Lookback Amounts
limits the amounts retained by IOUs to
the lesser of an IOU’s REP settlement
benefits or the amount the IOU would
have received under the REP. The
proposed FY 2009 REP benefits to the
IOUs would be significantly higher if,
instead of proposing to limit the
amounts the IOUs were entitled to in FY
2007 and FY 2008 to the amounts they
would have received under the REP
settlements, BPA had instead proposed
that the IOUs were entitled to the
recalculated REP benefits for those
years. BPA encourages parties to
propose alternative approaches to this
or other elements of BPA’s proposal to
address the Court’s decisions for the
agency to consider.
This section describes, in general,
BPA’s proposal for responding to recent
decisions of the Ninth Circuit noted
previously. In PGE, the Court held that
BPA’s REP Settlement Agreements were
inconsistent with the Northwest Power
Act. In a companion opinion, Golden
NW, the Court held that BPA
improperly allocated REP Settlement
Agreement costs to BPA’s preference
customers in its WP–02 power rates and
remanded the rates to BPA. Although
the Ninth Circuit in Golden NW also
found infirmities in BPA’s estimates of
fish and wildlife costs for the WP–02
rates, the rates nevertheless recovered
all of the costs of BPA’s fish and
wildlife commitments for FY 2002–
2006. BPA acknowledges that entities
may continue to assert that BPA had not
committed enough funding to fish and
wildlife activities during this period,
but as the Court notes, that is not a
matter determined in a rate proceeding.
As a result, BPA is not proposing any
changes in the WP–07 Supplemental
Proceeding to its fish and wildlife
commitments for FY 2002–2006. As
discussed elsewhere, BPA is proposing
a specific process, external to the rate
case, to ensure its forecasts for fish and
wildlife costs are as up-to-date as
possible for purposes of establishing
rates for FY 2009.
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In a subsequent opinion, Snohomish,
the Court remanded amendments to the
REP Settlement Agreements and a
provision regarding a Reduction of Risk
discount the Court found was based on
such Agreements. Three memorandum
opinions, released at the same time as
Snohomish, dismissed challenges to
BPA’s 2001 LRAs with PacifiCorp and
Puget Sound Energy.
BPA is proposing to respond to the
Court’s decisions by: (1) Determining
Lookback Amounts, which are the costs
associated with the REP settlements that
were improperly included in FY 2002–
2008 rates and therefore should be
recovered from IOUs and returned to
preference customers; (2) recovering
Lookback Amounts over time by
reducing future REP benefits due to
IOUs; and (3) concomitantly reducing
preference customers’ rates to reflect the
lower REP benefit payments. Because
BPA allocated REP settlement costs in
its WP–07 power rates in the same
manner as BPA allocated such costs in
its WP–02 rates, BPA has reopened its
WP–07 power rate proceeding to revise
its power rates for FY 2009.
1. REP Settlement Agreement
Background
In 1998, BPA’s Subscription Strategy
proposed offering BPA’s regional IOU
customers the option of signing RPSAs
to participate in a traditional REP or
signing REP Settlement Agreements for
FY 2002–2011. The REP Settlement
Agreements were to provide power and
monetary benefits to the IOUs’
residential and small farm consumers in
order to resolve disputes arising under
BPA’s implementation of the REP. Prior
to the development of the RPSAs and
REP Settlement Agreements in 2000, the
IOUs submitted letters to BPA stating
their intent to participate in the REP.
Through negotiations and a public
notice and comment administrative
proceeding, BPA developed prototype
RPSAs and REP Settlement Agreements.
BPA issued respective records of
decision on October 4, 2000, for the
RPSAs and REP Settlement Agreements.
BPA then offered the RPSAs and REP
Settlement Agreements to the IOUs.
All of the IOUs elected to execute the
REP Settlement Agreements. For FY
2002–2006, the Settlement Agreements
included 900 aMW of financial benefits
and 1000 aMW of power at a cost-based
rate, consistent with the Subscription
Strategy. Subsequent to the execution of
the REP Settlement Agreements, BPA
entered into LRAs with PacifiCorp and
Puget Sound Energy whereby BPA
bought back the power component of
the utilities’ REP Settlement Agreements
as part of BPA’s strategy to limit the
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financial impacts of the West Coast
energy crisis. Through amendments to
the REP Settlement Agreements signed
in 2004, benefits for FY 2007–2011 were
set at 2200 aMW of financial benefits.
BPA conducted the WP–02 rate
proceeding to establish power rates for
FY 2002–2006. BPA allocated the costs
of the REP settlements to the PF
Preference rate. A cost recovery
adjustment clause captured the costs of
the LRAs with PacifiCorp and Puget
Sound Energy. A number of parties
subsequently filed separate challenges
to BPA’s REP Settlement Agreements
and BPA’s WP–02 power rates in the
Ninth Circuit. On May 3, 2007, the
Court issued the PGE and Golden NW
opinions noted above.
2. Overview of Proposal
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a. FY 2002–2006 Rate Period
Together with the Court’s decision in
PGE, BPA interprets the Court’s remand
in Golden NW as requiring BPA to
remove the cost of the REP settlements
from the PF Preference rate. In removing
these costs, however, the Court’s
decisions do not require BPA to ignore
the fact that, in the absence of the REP
Settlement Agreements, the IOUs would
have received benefits during the FY
2002–2006 rate period under the
traditional REP. As noted previously,
prior to the development of the RPSAs
and REP Settlement Agreements, the
IOUs submitted letters to BPA stating
their intent to participate in the REP.
Consequently, absent BPA’s offer of REP
Settlement Agreements, BPA assumes
that all IOUs except Idaho Power would
have participated in the REP, the costs
of which would have been reflected in
setting BPA’s power rates.
In response to the Court’s decisions,
BPA proposes to determine the amount
of benefits provided to each IOU under
the REP settlements. BPA also proposes
to calculate the amount of REP benefits
each IOU would have received from
BPA during the FY 2002–2006 rate
period in the absence of the REP
Settlement Agreements. In order to
calculate such REP benefits, BPA
proposes to remove the REP settlement
costs from BPA’s WP–02 power rates
and replace them with costs associated
with a traditional REP. This change will
establish the PF Exchange rate that
would have been used to implement the
REP during the rate period. This
approach requires BPA to review and
decide a number of issues in the WP–
02 Final Proposal that were undecided
or rendered moot by the presence of the
REP Settlement Agreements. Failure to
allow parties to address these issues on
the merits would be inequitable. In
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addition, BPA must estimate the IOUs’
respective ASCs for the rate period,
which are used in conjunction with the
PF Exchange rate and the IOUs’
residential and small farm loads to
determine each IOU’s respective REP
benefits. BPA proposes to compare each
IOU’s REP benefits with the actual
payments made to that IOU under the
REP settlements.
Based on the resulting differences
between these two amounts, BPA will
determine the Lookback Amounts to be
recovered from each IOU and returned
to preference customers via lower rates,
as described in Section D below. Section
E describes BPA’s proposal for how the
Lookback Amounts will be recovered
over time. This approach responds to
the Court’s remand of the WP–02 rates
by effectively reimbursing, through
lower rates over time, preference
customers for costs that should not have
been included in the WP–02 preference
rates during the FY 2002–2006 rate
period.
In constructing this approach, BPA is
not proposing to recalculate any rates
other than the PF Exchange rate for the
FY 2002–2006 period. BPA is proposing
to recalculate only the PF Exchange rate
for this period because this is the rate
necessary to calculate the REP benefits
the IOUs would have received.
Consequently, this approach does not
require BPA to recalculate any other
rates for this period.
The determination of utility-specific
Lookback Amounts is complex. In
addition to the REP Settlement
Agreements, BPA must also account for
the Court’s decision in Snohomish,
which remanded to BPA the 2004
amendments to the REP Settlement
Agreements and the Reduction of Risk
discount that the Court found was based
on those Agreements. BPA also must
consider three memorandum opinions
that dismissed challenges to the LRAs.
In addition, the operation of the REP
would have accounted for existing
deemer balances, that is, amounts
accrued by exchanging utilities and
owed to BPA that must be eliminated
before REP benefits can be paid.
b. FY 2007–2008
BPA is proposing to adopt a similar
approach to that used for FY 2002–2006
to address BPA’s WP–07 rates for FY
2007 and FY 2008. The rates charged in
these years, like the WP–02 rates,
included REP settlement costs.
Although the Ninth Circuit has not
ruled on the validity of BPA’s WP–07
rates, the Court’s holdings in PGE,
Golden NW, and Snohomish implicate
the validity of the rates BPA established
for these years. Rather than wait for the
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Court to remand these rates to BPA in
a subsequent case, BPA proposes to
remedy these problems now. BPA’s
specific proposal is to adopt a remedy
similar to that described above; that is,
BPA proposes to remove the REP
settlement costs from power rates and
replace such costs with the costs of
providing benefits to IOUs under the
REP in FY 2007 and FY 2008. BPA will
then compare the benefits under the
REP to the payments each IOU received,
or would have received, under the REP
settlements for these years, determine
the appropriate difference, and propose
how this difference should be returned
to preference customers.
Once again, in constructing this
approach, BPA is not proposing to
recalculate any rates other than the PF
Exchange rate for the FY 2007–2008
period. BPA is proposing to recalculate
only the PF Exchange rate for this
period because this is the rate necessary
to calculate the REP benefits the IOUs
would have received. Consequently, this
approach does not require BPA to
recalculate any other rates for this
period.
B. REP Settlement Agreement Benefits
Paid During FY 2002–2008
The first step in responding to the
PGE, Golden NW, and Snohomish
decisions is to calculate the amount of
benefits paid to each IOU under the REP
settlements during FY 2002–2008.
These benefits include, for example, the
Conservation and Renewables Discount
(C&RD) and Conservation Rate Credit
(CRC), and a power sale to PGE. BPA
reviewed its accounting records and
determined the amounts paid to each
IOU as well as the amounts that would
have been paid had payments to the
IOUs not been suspended. These
amounts are detailed in the Lookback
Study. This determination also
identifies the source of the payments,
i.e., the portion of the payments made
under the REP Settlement Agreements,
LRAs, etc. The total benefits paid were
approximately $1.96 billion for FY
2002–2006 and $168 million for FY
2007. Benefits that would have been
paid in the latter half of FY 2007 and
in FY 2008 after the suspension of
payments subsequent to the Court’s
rulings in May 2007 would have totaled
$505 million.
C. Proposal for Determining REP
Benefits for FY 2002–2008
As previously described, BPA
proposes to determine the amount of
REP benefits that would have been paid
to each IOU in the absence of the REP
settlements. These costs would have
been included in the WP–02 and WP–
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07 power rates for FY 2002–2008
instead of the costs of the REP
settlements. In order to make this
determination, BPA must evaluate two
key elements of the REP: (1) The WP–
02 and WP–07 PF Exchange rates and
(2) the IOUs’ respective ASCs during FY
2002–2008. BPA’s proposals for these
two rate periods are described below.
1. BPA’s Proposal for Calculating REP
Benefits for FY 2002–2006
a. The PF Exchange Rate for FY 2002–
2006
BPA proposes to recalculate the PF
Exchange rate for FY 2002–2006
assuming that all IOUs except Idaho
Power would have participated in the
REP in the absence of the REP
Settlement Agreements. To develop this
rate, BPA proposes to return to its WP–
02 Supplemental Rate Proposal and
revise its base rates with altered input
assumptions consistent with
information available at that time and
with reconsideration of section 7(b)(2)
rate test issues that were previously
undecided or rendered moot. The
resulting PF Exchange rate is the rate
that would have been used by BPA to
calculate benefits under the traditional
REP during FY 2002–2006.
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b. IOU Average System Costs (ASC) for
FY 2002–2006
Although BPA’s PF Exchange rate is
a critical element of the REP, actual REP
benefits paid to each IOU are not
determined in BPA’s rate cases. BPA’s
rate cases only forecast the expected
levels of REP benefits, which comprise
the expected costs that will be included
in rates for the rate period. The actual
level of REP benefits a utility receives is
determined during the rate period as the
REP is implemented and is based on a
comparison of the PF Exchange rate and
a utility’s filed ASC, multiplied by the
utility’s residential and small farm
loads. To calculate REP payments for FY
2002–2006, BPA would normally use
filed ASCs. The IOUs, however, did not
make ASC filings with BPA during the
WP–02 period because the REP
Settlement Agreements did not require
such filings. Consequently, to calculate
the REP benefits that would have been
paid during the WP–02 rate period, BPA
proposes to determine annual ASC for
each IOU during the rate period.
To determine these annual ASCs, BPA
proposes to look to FERC Form 1 data
filed by each IOU with FERC for FY
2002–2006. From these historical data,
BPA proposes to calculate an annual
ASC for each utility by following the
functionalization rules as set forth in the
1984 ASC Methodology. Relying on the
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1984 Methodology is a conservative
assumption given that BPA would likely
have re-opened the ASC Methodology
had the IOUs not executed the REP
Settlement Agreements. The imputed
ASCs, in conjunction with the
reconstituted PF Exchange rate and
actual exchange loads, are used to
calculate utility-specific amounts of REP
benefits that would have been paid
during the WP–02 rate period.
2. BPA’s Proposal for Calculating REP
Benefits for FY 2007–2008
Similar to the FY 2002–2006 period,
BPA’s PF Preference rate for FY 2007–
2008 included REP settlement costs. To
remedy this infirmity, BPA proposes to
use a similar construct as described
previously to determine the REP
benefits the IOUs would have received
for FY 2007–2008; that is, BPA proposes
to recalculate the PF Exchange rate for
FY 2007–2008 assuming an REP, and
then impute annual ASCs for each IOU
customer for FY 2007–2008 to
determine the REP benefits that would
have been paid during this period.
a. BPA’s PF Exchange Rate for FY 2007–
2008
BPA is proposing to conduct the
section 7(b)(2) rate test in this
Supplemental Proposal in a manner
consistent with the rate test used in the
reformulation of the PF Exchange rate
for FY 2002–2006. The results of the
rate test, in conjunction with all other
assumptions used in setting rates during
the WP–07 rate proceeding, will be used
in recalculating the PF Exchange rate for
FY 2007–2008.
b. IOU Average System Costs for FY
2007–2008
Consistent with BPA’s proposal to
determine the REP benefits IOUs would
have received in FY 2002–2006, BPA
proposes to determine IOU ASCs for FY
2007–2008 relying on BPA’s 1984 ASC
Methodology. BPA is proposing to use
FERC Form 1 data from 2006 and a
trend analysis to project ASCs for FY
2007–2008. BPA believes this approach
approximates what the actual ASCs
would be for FY 2007–2008. As with the
FY 2002–2006 rate period, these
imputed ASCs, in conjunction with the
reconstituted PF Exchange rate and
actual and forecast exchange loads, are
used to calculate a utility-specific
amount of REP benefits that would have
been paid for FY 2007–2008.
D. Determination of Lookback Amounts
Determining the Lookback Amounts is
not a simple proposition. A number of
factors affect the amount of settlement
benefits received by the IOUs and, more
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7553
importantly, whether the IOUs are
entitled to retain such benefits in the
absence of the REP Settlement
Agreements. For example, although the
Court found the REP Settlement
Agreements unlawful, the Court
remanded the 2004 amendments to
BPA. The Court also remanded the
Reduction of Risk discount, also called
the ‘‘litigation penalty’’ by some
preference customers, to BPA. In
addition, the Court issued three
memorandum opinions dismissing
challenges to the LRAs.
As a result, BPA cannot simply
subtract the REP benefits otherwise due
the IOUs from the benefits paid under
the REP Settlement Agreements, 2004
amendments, and LRAs to calculate the
amount to be recovered from the IOUs.
In addition, implementation of the
traditional REP would have meant that
the deemer balances for certain IOUs
would have to be considered in
determining the REP benefits that would
have been paid absent the REP
Settlement Agreements. This section
describes BPA’s proposal for
determining the Lookback Amounts.
1. Treatment of Deemer Amounts
RPSAs are the contracts that
implement the REP. BPA’s 1981 RPSA
established what was called a ‘‘deemer
account.’’ In the event that an
exchanging utility’s ASC fell below the
PF Exchange rate, rather than pay BPA,
the utility would accumulate a balance
in a deemer account based on the
difference between its ASC and the PF
Exchange rate multiplied by the utility’s
eligible exchange load. The 1981 RPSA
provided that any obligations incurred
under that RPSA would continue until
satisfied, even if the RPSA expired. The
RPSA also provided that the utility must
repay its deemer balance before
receiving any positive REP benefits.
Idaho Power, Northwestern Energy, and
Avista Corporation (Avista) all have
extant deemer balances.
BPA proposes that its determination
of the amount of REP benefits that
would have been provided to the IOUs
should account for utilities’ deemer
balances. Therefore, BPA proposes that
any REP benefits calculated for an IOU
with a deemer balance will first be used
to extinguish its deemer balance before
being compared to the REP settlement
payments to establish a Lookback
Amount for that IOU. Under BPA’s
proposal, Northwestern Energy and
Avista exhaust their deemer balances in
FY 2005 and FY 2007, respectively.
Under BPA’s determination of REP
benefits, absent the REP settlements,
Idaho Power does not qualify for REP
benefits during the FY 2002–2008
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period so there are no reductions to its
deemer balance and its Lookback
Amount is equal to the REP settlement
benefits it received.
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2. Cap on REP Benefits Credited Against
Settlement Payments
BPA proposes a second condition on
the calculation of the amount to be
recovered from each IOU for FY 2002–
2008. In calculating this Lookback
Amount for each utility, BPA proposes
that REP benefits that exceed the REP
settlement benefits shall not be credited
to the Lookback Amount. Said another
way, an IOU cannot receive more
benefits under the REP than it received,
or would have received, under the REP
settlements. This condition is applied
each year for FY 2002–2008.
3. Treatment of Reduction of Risk
Discount and Load Reduction
Agreements
As previously mentioned, the LRAs
with PacifiCorp and Puget Sound
Energy are contracts wherein BPA
bought back power from these two IOUs
to limit exposure to the high and
volatile market prices of the West Coast
energy crisis. No party filed a challenge
to the LRAs within the Northwest Power
Act’s 90-day statute of limitations. Two
petitions for review were filed with the
Ninth Circuit challenging BPA’s
unsuccessful attempts to develop a
broad settlement of all outstanding
litigation against BPA. The Court noted
that the petitions were challenging
actions that never occurred and
dismissed the petitions for lack of
jurisdiction. Another petition was filed
that challenged the LRAs, but it was
filed two and one half years after
expiration of the 90-day statute of
limitations. The Court noted that the
only issue raised in the petition
concerned the Reduction of Risk
Discount provision of the LRAs. Having
dealt with the Reduction of Risk
Discount in Snohomish, the Court
dismissed the petition challenging the
LRAs as moot.
In light of the Court’s actions, BPA
proposes to treat the LRA payments to
PacifiCorp and Puget Sound Energy in
the following manner. First, BPA will
assume that the total REP settlement
benefits paid to these two IOUs include
the REP Settlement Agreement benefits,
the LRA payments, and the C&RD/CRC
benefits. BPA proposes that PacifiCorp
and Puget Sound Energy (Puget) keep
the lesser of the REP settlement benefits
or the REP benefits the utilities would
have received in the absence of the REP
Settlement Agreements, but not less
than the amount of the LRA payments.
This proposal effectively treats the LRA
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payments to PacificCorp and Puget
Sound Energy as ‘‘protected’’ payments
that are not subject to recovery as part
of their Lookback Amounts.
In Snohomish, the Court held that the
Reduction of Risk Discount was
founded on the original REP Settlement
Agreements and remanded the issue to
BPA. Therefore, BPA proposes to treat
the Reduction of Risk discount
payments as suffering the same fate as
the REP Settlement Agreement
payments. Any amount paid to
PacifiCorp and Puget for the Reduction
of Risk Discount will be included in
their REP Settlement Agreement
benefits and will therefore be subject to
recovery through the lookback process.
due will be determined by the
Administrator in each rate case. The
reduced REP payments to IOUs will
result in lower PF Preference rates for
FY 2009 and beyond until Lookback
Amounts are fully amortized. These
lower PF rates constitute a portion of
the compensation to preference
customers for the amounts they
overpaid in FY 2002–2008 power rates.
An additional portion of the
compensation may occur as provided in
Standstill Payment Agreements, if
offered, for those preference customers
that sign such agreements or via
customer-specific credits on FY 2009
power bills if such agreements are not
signed.
The reduction in the amounts of REP
4. Results
benefits that would have otherwise been
due will be credited against each IOU’s
The application of the previous three
Lookback Amount. This practice will
sections results in annual Lookback
continue as needed each rate period
Amounts for each IOU. BPA is
until each IOU has amortized its total
proposing to escalate the annual
Lookback Amounts for FY 2002–2006 to Lookback Amount, including interest.
BPA proposes that unamortized
2007 dollars to adjust for the effects of
Lookback balances will accrue interest.
inflation. The resulting cumulative
The proposed reduction in REP benefits
Lookback Amounts for each IOU, in
for FY 2009 is an amount that is
2007 dollars for FY 2002–2007 are
expected to amortize each IOU’s
provided in Table 3.
Lookback Amount plus accrued interest
within 20 years, with the exception of
TABLE 3.—PROPOSED CUMULATIVE
Idaho Power. The assumptions and
LOOKBACK AMOUNTS
proposal with regard to Idaho Power are
[Millions of 2007 dollars]
described in more detail below.
BPA expects that all IOUs except
Proposed
Idaho Power will amortize their
Utility name
lookback
amounts
respective Lookback Amounts,
including interest, within 20 years
Avista ........................................
$62.1 based on a set of simple assumptions
Idaho Power .............................
96.6 regarding the future. These assumptions
Northwestern Energy ................
7.7
are:
PacifiCorp .................................
239.4
1. The FY 2009 individual IOU REP
Portland General Electric .........
64.1
Puget Sound Energy ................
150.5 benefits paid continue in future rate
periods until such time each IOU fully
Total ......................................
620.4 amortizes its Lookback Amount;
2. Each IOU’s FY 2009 REP benefits
The Lookback Amounts in Table 3
amount (before reductions applied for
assume that BPA offers, and the IOUs
Lookback Amounts) increases by 2.5
sign, the Interim Agreements. In the
percent per year (as a consequence of
absence of Interim Agreements, no REP
growth in eligible exchange loads and/
benefits will be paid in FY 2008,
or increases in IOU ASCs and/or
creating an amount of REP benefits
changes in PF Exchange rates, none of
otherwise due to the IOUs for that year,
which is specifically forecasted or
which will be used to reduce
otherwise modeled); and
3. Interest accrues on unamortized
accumulated Lookback Amounts by
Lookback balances at the rate of 5.03
$189 million.
percent per year.
E. Application of the Results of the
BPA proposes to proportionally
Lookback Analysis
reduce each IOU’s benefits due for FY
Because the IOUs have already passed 2009 such that the aggregate benefit
REP Settlement and LRA benefits on to
paid, before consideration of any
their residential and small farm
deemer obligations, for all IOUs is 210
customers for FY 2002–2006 and part of million. This amount represents a
FY 2007, BPA proposes to recover
balance between ensuring that regional
Lookback Amounts from the IOUs by
residential and small farm consumers
reducing future REP benefits
receive benefits from the Residential
determined to be otherwise due them.
Exchange Program while returning to
The amount of the reduction in benefits preference customers the overpayments
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to IOUs that occurred under the REP
settlements. This aggregate benefit is in
the middle of the $200 million to $220
million range contained in the
Recommendations of Representatives of
the Investor-Owned and Certain
Consumer-Owned Utilities Regarding
the Residential Exchange Benefits for
Customers Served by the Pacific
Northwest Investor-Owned Utilities
dated November 7, 2007. BPA
understands that this document enjoys
broad, albeit not universal, customer
support. BPA views such support as a
measure of the reasonableness of its
approach to recovering the Lookback
Amounts over time.
Table 4 shows FY 2009 REP benefits
due and REP benefits paid before
consideration of any deemer obligations.
TABLE 4.—FY 2009 REP BENEFITS
DUE AND BENEFITS PAID BEFORE
DEEMER ADJUSTMENT
[Millions of dollars]
FY 2009
REP benefits due
Utility name
FY 2009
REP benefits paid
$27.8
9.2
$23.3
7.7
7.6
50.8
6.4
42.7
Avista ................
Idaho Power .....
Northwestern
Energy ...........
PacifiCorp .........
Portland General
Electric ..........
Puget Sound
Energy ...........
54.6
45.8
100.2
84.1
Total ..............
250.2
210.0
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BPA maintains the position that Idaho
Power has a substantial deemer balance
at the end of FY 2008. BPA is proposing
to apply the same treatment to Idaho
Power’s deemer balance for FY 2009
that was applied when determining the
Lookback Amounts for FY 2002–2008.
Specifically, REP benefits will first be
applied toward deemer balances. Only
when Idaho Power’s deemer balance is
extinguished would REP benefits be
available to apply against Lookback
Amounts and to provide positive REP
benefits to Idaho Power. Based on Idaho
Power’s current deemer balance and
reasonable expectations of future REP
benefits, Idaho Power is not expected to
amortize its Lookback Amount by 2028.
BPA acknowledges that Idaho Power
disputes its current deemer balance and
has requested to explore with BPA the
possibility of settling this dispute.
F. Summary
In summary, BPA’s proposal responds
to the Court’s rulings in several ways to
remedy the improper allocation of REP
settlement costs to the PF Preference
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rate. First, the WP–07 Supplemental
Proposal results in an average PF
Preference rate of $26.2/MWh—about a
four percent (4%) reduction from
current rates. This proposed reduction
results from several changes or revisions
to the WP–07 Final Studies. The most
significant change is a reduction in the
costs of the REP for FY 2009 from about
$336 million to $202 million, which
includes $39 million of the Lookback
Amount.
Second, BPA is determining the
magnitude of the Lookback Amounts for
FY 2002–2007 that need to be recovered
from the region’s IOUs and returned to
public utilities. BPA proposes to recover
this total, approximately $620 million,
out of future REP benefits, starting with
the $39 million for FY 2009 noted
above. BPA proposes that the amount of
future Lookback Amounts recovered,
and by extension the associated PF rate
reduction, will be decided in each
subsequent rate case.
Lastly, BPA is proposing to provide
public utilities with either a one-time
payment or a credit on their power bills
for the difference between the REP
settlements costs in power rates for FY
2007–2008, and the amount of FY 2007–
2008 REP benefits the IOUs would be
paid under BPA’s proposal. If BPA
offers, and preference customers sign,
Standstill Payment Agreements, they
will receive a portion of this credit in
FY 2008 and the remainder in FY 2009.
If they do not sign Standstill Payment
Agreements, or the agreements are not
offered, preference customers will
receive the credit in FY 2009. BPA has
the financial reserves to provide this FY
2008–2009 payment or credit of about
$315 million because BPA has been
collecting REP settlement costs in the
PF Preference rate but has not been
paying benefits to the IOUs since the
Court’s May, 2007, rulings.
Part VII—2007 Supplemental
Wholesale Power Rate Schedules (FY
2009) and 2007 Supplemental General
Rate Schedule Provisions (GRSPs) (FY
2009)
BPA’s proposed 2007 Supplemental
Wholesale Power Rate Schedules and
GRSPs, as well as the Section 7(b)(2)
Legal Interpretation and Section 7(b)(2)
Implementation Methodology,
incorporated by reference as a part of
this Notice, are available for viewing
and downloading on BPA’s Web site at
https://www.bpa.gov/corporate/ratecase.
A copy of the proposed rate schedules
and GRSPs are also available for
viewing in BPA’s Public Reference
Room at the BPA Headquarters, 1st
Floor, 905 NE 11th Avenue, Portland,
OR.
PO 00000
Frm 00050
Fmt 4703
Sfmt 4703
7555
Issued this 1st day of February, 2008.
Stephen J. Wright,
Administrator and Chief Executive Officer.
[FR Doc. E8–2339 Filed 2–7–08; 8:45 am]
BILLING CODE 6450–01–P
ENVIRONMENTAL PROTECTION
AGENCY
[ER–FRL–6695–7]
Environmental Impacts Statements;
Notice of Availability
Responsible Agency: Office of Federal
Activities, General Information (202)
564–7167 or https://www.epa.gov/
compliance/nepa/
Weekly receipt of Environmental Impact
Statements
Filed 01/28/2008 through 02/01/2008
Pursuant to 40 CFR 1506.9
EIS No. 20080035, Draft EIS, IBR, WA,
Yakima River Basin Water Storage
Feasibility Study, Create Additional
Water Storage, Benton, Yakima,
Kittitas Counties, WA, Comment
Period Ends: 03/31/2008, Contact:
David Kaumheimer 509–575–5848
Ext. 612.
EIS No. 20080036, Final EIS, GSA, CO,
Denver Federal Central Site Plan
Study, Master Site Plan,
Implementation, City of Lakewood,
Jefferson County, CO, Wait Period
Ends: 03/10/2008, Contact: Lisa D.
Morpurgo 303–236–8000 Ext. 5039.
EIS No. 20080037, Draft EIS, AFS, ID,
Yakus Creek Project, Proposes Timber
Harvest, Watershed Improvement, and
Access Management Activities,
Lochsa Ranger District, Clearwater
National Forest, Idaho County, ID,
Comment Period Ends: 03/24/2008,
Contact: Craig Trulock 208–926–4274.
EIS No. 20080038, Draft EIS, BLM, WY,
West Antelope Coal Lease
Application (Federal Coal Lease
Application WYW163340),
Implementation, Converse and
Campbell Counties, WY, Comment
Period Ends: 04/08/2008, Contact:
Sarah Bucklin 307–261–7587.
EIS No. 20080039, Final EIS, BLM, NV,
Kane Springs Valley Groundwater
Development Project, To Construct
Infrastructure Required to Pump and
Convey Groundwater Resources,
Right-of-Way Application, Lincoln
County Water District, Lincoln
County, NV, Wait Period Ends: 03/10/
2008, Contact: Penny Wood 775–861–
6466.
EIS No. 20080040, Draft EIS, IBR, NV,
Folsam Lake State Recreation Area &
Folsam Powerhouse State Historic
Park, General Plan/Resource
Management Plan, Implementation, El
E:\FR\FM\08FEN1.SGM
08FEN1
Agencies
[Federal Register Volume 73, Number 27 (Friday, February 8, 2008)]
[Notices]
[Pages 7539-7555]
From the Federal Register Online via the Government Printing Office [www.gpo.gov]
[FR Doc No: E8-2339]
-----------------------------------------------------------------------
DEPARTMENT OF ENERGY
Bonneville Power Administration
2007 Supplemental Wholesale Power Rate Adjustment Proceeding,
Public Hearings, and Opportunities for Public Review and Comment
AGENCY: Bonneville Power Administration (BPA), Department of Energy
(DOE).
ACTION: Notice of Proposed Wholesale Power Rates (Notice). BPA File
No.: WP-07.
-----------------------------------------------------------------------
SUMMARY: 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 they are adequate to
recover, in accordance with sound business principles, the costs
associated with the acquisition, conservation and transmission of
electric power, and to recover the Federal investment in the Federal
Columbia River Power System (FCRPS) and other costs incurred by BPA.
BPA is reopening its WP-07 wholesale power rate proceeding, which
established power rates for Fiscal Years (FY) 2007-2009, in order to
respond to recent decisions from the United States Court of Appeals for
the Ninth Circuit (Ninth Circuit or Court) and to revise rates for FY
2009.
This 2007 Supplemental Wholesale Power Rate Adjustment Proceeding
(WP-07 Supplemental Proceeding) responds to the Court's remand of BPA's
WP-02 power rates for FY 2002-2006. This proceeding also responds to a
separate Court decision that found BPA's 2000 Residential Exchange
Program (REP) Settlement Agreements (REP Settlement Agreements)
contrary to law. In response, BPA proposes to determine the amounts of
REP settlement costs improperly included in FY 2002-2008 power rates,
recover those amounts from investor owned utility customers (IOUs) over
time and return improperly included amounts to preference customers.
The WP-07 Supplemental Proceeding also includes proposed revisions to
BPA's Section 7(b)(2) Legal Interpretation and Section 7(b)(2)
Implementation Methodology.
Persons that previously intervened in BPA's WP-07 Wholesale Power
Rate Adjustment Proceeding automatically continue their party status in
the WP-07 Supplemental Proceeding. Other persons wishing to become a
formal party to the proceeding must file a petition to intervene,
notifying BPA in writing of their intention to do so in conformance
with the requirements stated in this Notice.
DATES: Petitions to intervene must be received no later than 5 p.m.,
Pacific Standard Time, on February 18, 2008. Non-party participants may
make written comments between February 8, 2008, and May 5, 2008.
Comments must be received by 5 p.m., Pacific Daylight Savings Time, on
May 5, 2008, in order to be considered in the Supplemental Record of
Decision (Supplemental ROD). (See Part III (A) for more information.)
ADDRESSES: Petitions to intervene should be directed to Robert Welsh,
Hearing Clerk, LP-7, Bonneville Power Administration, 905 NE 11th
Avenue, Portland, OR 97232 or by e-mail to: wp07rate@bpa.gov. In
addition, a copy of the petition must be served concurrently on BPA's
General Counsel and directed to Kurt R. Casad, LP-7, Office of General
Counsel, Bonneville Power Administration, 905 NE 11th Avenue, Portland,
OR 97232 or by e-mail to: krcasad@bpa.gov. See Part III (A) for more
information.) Written comments by non-party participants must be
received by 5 p.m. Pacific Daylight Savings Time, on May 5, 2008, in
order to be considered in the Supplemental Record of Decision
(Supplemental ROD). Written comments may be made as follows: In person
at the field hearings (see schedule and locations in Part I of this
Notice), online at BPA's Web site: https://www.bpa.gov/comment, or by
mail to: BPA Public Affairs, DKE-7, P.O. Box 14428, Portland, OR 97293-
4428. Please identify written or electronic comments as ``WP-07
Supplemental Proceeding.'' The Supplemental ROD will consider and
address the comments received.
The WP-07 Supplemental Proceeding will begin with a prehearing
conference at 9 a.m., Pacific Standard Time, on February 19, 2008, held
in the BPA Rates Hearing Room, 2nd Floor, 911 NE 11th Avenue, Portland,
OR. Due to increased security requirements, attendees should allow
additional time to enter the building and complete the required
screening process. Photo identification will be required for entry. BPA
will release its 2007 Supplemental Wholesale Power Rate Proposal (WP-07
Supplemental Proposal) and supporting documents at the prehearing
conference. Compact discs (CDs) containing the WP-07 Supplemental
Proposal will be provided to the parties at the prehearing conference.
The WP-07 Supplemental Proposal will also be available on BPA's Web
site at https://www.bpa.gov/corporate/ratecase.
FOR FURTHER INFORMATION CONTACT:
Ms. Heidi Helwig, Public Affairs Specialist, Public Affairs Office,
DKE-7, P.O. Box 3621, Portland, OR 97208. Interested persons may also
call 503-230-3458 or 1-800-622-4519 (toll-free)
Ms. Leslie M. Dimitman, Paralegal Specialist, Office of General
Counsel, LP-7, P.O. Box 3621, Portland, OR 97208. Interested persons
may also call Ms. Dimitman at (503) 230-5515, or the general BPA toll-
free numbers 1-800-282-3713 (answered Monday through Friday 6:30 a.m.
to 5 p.m.) or 1-866-879-2303 (answered by voicemail)
Information also may be obtained from:
Mr. Raymond D. Bliven, Power Rates Manager--PFR-6, P.O. Box 3621,
Portland, OR 97208
Ms. Suzanne B. Cooper, Power Policy and Rates Manager--PF-6, P.O. Box
3621, Portland, OR 97208
Ms. Elizabeth Evans, Policy Analysis Manager--PFB-6, P.O. Box 3621,
Portland, OR 97208
Mr. Garry Thompson, Manager, Eastern Power Business Area; Mr. Ken
Hustad, Senior Customer Account Executive; Ms. Carol Hustad, Customer
Account Executive; Mr. Michael Normandeau, Customer Account Executive,
Eastern Power Business Area--PSE, 707 W. Main, Suite 500, Spokane, WA
99201
Mr. Scott Coe, Manager, Western Power Business Area; Mr. Charles
Forman, Customer Account Executive; Ms. Claire Hobson, Customer Account
Executive; Ms. Tina Ko, Customer Account Executive; Ms. Theresa
Rockwood, Customer Account
[[Page 7540]]
Executive; Western Power Business Area--PSW-6, P.O. Box 3621, Portland,
OR 97208
Mr. Larry King, Customer Account Executive, 2700 Overland, Burley, ID
83318
Mr. C. T. Beede, Customer Account Executive, P.O. Box 40, Big Arm, MT
59910
Mr. Dan Bloyer, Customer Account Executive, 1011 SW Emkay Drive, Suite
211, Bend, OR 97702
Mr. Larry Felton, Senior Account Executive, Kootenai Building, Room
215, N. Power Plant Loop, Richland, WA 99352-0968
Mr. Stuart Clarke, Senior Customer Account Executive; Mr. George Reich,
Senior Customer Account Executive; Ms. Shannon Greene, Customer Account
Executive; Ms. R. Kirsten Watts, Customer Account Executive; 909 First
Avenue, Suite 380, Seattle, WA 98104-3636
SUPPLEMENTARY INFORMATION:
Table of Contents
I. Introduction and Procedural Background
II. Policy Guidance and Scope of Hearing
III. Public Participation
IV. Summary of WP-07 Supplemental Proposal and Major Studies
V. Section 7(b)(2) Legal Interpretation and Implementation
Methodology
VI. Summary of Proposal To Respond to the Court's Opinions Regarding
BPA's 2000 REP Settlement Agreements, WP-02 Rates, and by Extension,
WP-07 Rates
VII. 2007 Supplemental Wholesale Power Rate Case Schedules (FY 2009)
and 2007 Supplemental General Rate Schedule Provisions (FY 2009)
Part I--Introduction and Procedural Background
A. Overview and Background to This Rate Filing
BPA is proposing to conduct a WP-07 Supplemental Proceeding in
order to: (1) Adjust BPA's FY 2009 power rates consistent with recent
decisions of the Ninth Circuit regarding BPA's WP-02 power rates for FY
2002-2006; and (2) respond to the Court's decision finding BPA's REP
Settlement Agreements contrary to the Northwest Power Act.
Due to the time it takes to conduct a general rate adjustment
proceeding, BPA determined that its first opportunity to establish
revised power rates to conform to the Court's opinions was prior to the
one-year FY 2009 rate period. Because BPA's WP-07 rates (FY 2007-2009)
are currently before the Federal Energy Regulatory Commission (FERC)
for final approval, BPA asked FERC to stay its review until BPA was
able to conduct a supplemental rate proceeding to address the issues
noted above. This will permit FERC to review a single supplemented
record supporting BPA's proposed rates for FYs 2007, 2008, and 2009.
In developing BPA's WP-02 power rates, BPA's revenue requirement
included anticipated costs of REP Settlement Agreements with six
regional IOUs. BPA allocated the majority of these settlement costs to
the Priority Firm Power (PF) Preference rate. Following final approval
of BPA's WP-02 rates by FERC, a number of parties challenged the WP-02
power rates in the Ninth Circuit. In Golden NW Aluminum, Inc. v.
Bonneville Power Admin., 501 F.3d 1037 (9th Cir. 2007) (Golden NW), the
Court held BPA had improperly allocated REP Settlement Agreement costs
to BPA's rates for preference customers. During the litigation of
Golden NW, but prior to the Court's decision, BPA conducted a
subsequent hearing (WP-07) to establish power rates for FY 2007-2009.
In establishing these rates, BPA allocated REP settlement costs in the
same manner as in BPA's WP-02 rates. Because the Court held in Golden
NW that BPA's allocation of REP settlement costs in its WP-02 rates was
improper, BPA's allocation of such costs in the WP-07 rates is
similarly flawed.
In addition, the Court held that BPA's WP-02 fish and wildlife cost
estimates, and by extension the rates set pursuant to those estimates,
were not supported by substantial evidence. The Court indicated BPA
relied on outdated assumptions and had not appropriately considered
information presented regarding its fish and wildlife costs. BPA's
subsequent approach to forecasting fish and wildlife costs in the
development of its WP-07 rates differed from the approach BPA used in
developing its WP-02 rates. Nonetheless, as described in more detail in
Part II.A.5, BPA is taking steps to ensure that its final WP-07
Supplemental rates for FY 2009 are based on the most recent projections
of fish and wildlife costs available at the time of rate development.
In a procedural forum separate from the WP-07 Supplemental Proceeding,
BPA will provide opportunities for fish and wildlife managers and
others to provide input to BPA regarding BPA's fish and wildlife
program costs for FY 2009. Decisions made based on the information
gained from this separate program cost review forum will be used in the
development of BPA's final WP-07 Supplemental rates.
In a companion case to Golden NW, the Court held that BPA's REP
Settlement Agreements with the IOUs were contrary to the Northwest
Power Act. Portland General Elec. Co. v. Bonneville Power Admin., 501
F.3d 1009 (9th Cir. 2007) (PGE). Also, subsequent to the Golden NW and
PGE decisions, the Court reviewed three petitions for review
challenging Load Reduction Agreements (LRAs) BPA executed with two IOUs
during the energy crisis of 2000-2001. The Court dismissed two of the
petitions for lack of jurisdiction and one petition as moot. The Court
also reviewed challenges to amendments to the REP Settlement Agreements
signed in 2004. In Public Utility Dist. No. 1 of Snohomish County,
Wash. v. Bonneville Power Admin., 506 F.3d 1145 (9th Cir. 2007)
(Snohomish), the Court remanded the amendments and a contract provision
establishing a Reduction of Risk Discount to BPA. BPA must respond to
the foregoing decisions. Because the ratemaking and REP issues are
interrelated, BPA is proposing to address its response to the Court's
decisions in the WP-07 Supplemental Proceeding.
In summary, this WP-07 Supplemental Proceeding is being held for
four primary purposes: (1) To establish new power rates for FY 2009;
(2) to determine the amount of benefits that BPA's IOU customers
received, or would have received, from FY 2002 through FY 2008 under
REP settlements; (3) to determine the amount of REP benefits the IOUs
would have received in the absence of the REP settlements; and (4) to
address any difference between these two amounts. Specifically, the
revised power rates for FY 2009 include the PF Preference rate and the
PF Exchange rate. The average PF Preference rate of $26.2/MWh, about a
four percent (4%) reduction, results largely from the reduced REP
costs. The revised PF Exchange rate is used to determine REP benefits
in FY 2009 As part of this process, BPA is also proposing revisions to
BPA's Section 7(b)(2) Legal Interpretation and Section 7(b)(2)
Implementation Methodology. An introduction to BPA's WP-07 Supplemental
Proposal is contained in Part IV of this Notice. A summary of BPA's
proposal regarding the calculation of REP benefits for FY 2002-2008 is
contained in Part VI.
B. Legal Requirements
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. These procedures include, among other things: publication
of a notice of the proposed rates in the Federal Register; one or more
hearings conducted as expeditiously as practicable by a Hearing
Officer; public opportunity to provide both oral and written views
[[Page 7541]]
related to the proposed rates; opportunity to offer refutation or
rebuttal of submitted material; and a decision by the Administrator
based on the record. This proceeding is governed by Sec. 1010 of BPA's
Rules of Procedure Governing Rate Hearings, 51 FR 7611 (1986) (BPA
Hearing Procedures). These procedures implement the statutory section
7(i) requirements.
Section 1010.7 of the BPA Hearing 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 BPA's rate case by other
Executive Branch agencies, Congress, existing or potential BPA
customers (including tribes), and nonprofit or public interest groups
are considered outside communications and are subject to the ex parte
rule. The general rule does not apply to communications relating to:
(1) Matters of procedure only (the status of the rate case, 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 BPA is responsible for under statutes other than the ratemaking
provisions; or (5) matters that 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 August 18, 2008.
The Bonneville Project Act, 16 U.S.C. 832, the Flood Control Act of
1944, 16 U.S.C. 825s, the Federal Columbia River Transmission System
Act, 16 U.S.C. 838, and the Northwest Power Act, 16 U.S.C. 839, provide
guidance regarding BPA ratemaking. The Northwest Power Act requires BPA
to set rates that are sufficient to recover, in accordance with sound
business principles, the cost of acquiring, conserving and transmitting
electric power, including amortization of the Federal investment in the
FCRPS over a reasonable period of years, and certain other costs and
expenses incurred by the Administrator.
BPA's 2007 Supplemental Wholesale Power Rate Schedules (FY 2009)
and 2007 Supplemental General Rate Schedule Provisions (GRSPs) (FY
2009), as well as the Section 7(b)(2) Legal Interpretation and Section
7(b)(2) Implementation Methodologye, are available for viewing and
downloading on BPA's Web site at https://www.bpa.gov/corporate/ratecase
as discussed in Part VII of this Notice. The studies addressing the
factors used to develop these rates are listed in Part IV and will be
available for examination beginning February 19, 2008, at BPA's Public
Information Center, BPA Headquarters Building, 1st Floor, 905 NE 11th
Avenue, Portland, Oregon, and will be provided to parties at the
prehearing conference to be held on February 19, 2008, beginning at 9
a.m., Pacific Standard Time, Room 223, 911 NE 11th Avenue, Portland,
Oregon.
Copies of the studies and documentation can be downloaded from
BPA's Web site at https://www.bpa.gov/corporate/ratecase or can be
requested (on a compact disc or hard copy) by calling BPA's document
request line toll-free at: 1-800-622-4519.
A formal evidentiary rate hearing will be conducted that is open to
rate case parties. Interested parties that did not previously intervene
in BPA's WP-07 power rate proceeding must file petitions to intervene
in order to take part in the WP-07 formal hearing. A proposed schedule
for the WP-07 Supplemental Proceeding is stated below.
The Hearing Officer will establish a final schedule at the
prehearing conference.
Prehearing/BPA Direct Case..................... 02/19/08
Clarification.................................. 02/27/08-02/29/08
Motions to Strike.............................. 03/07/08
Data Request Deadline.......................... 03/07/08
Answers to Motions to Strike................... 03/14/08
Data Response Deadline......................... 03/14/08
Spokane, WA Field Hearing...................... 03/18/08
Portland, OR Field Hearing..................... 03/20/08
Parties file Direct Cases...................... 03/28/08
Clarification.................................. 04/07/08-04/09/08
Motions to Strike.............................. 04/11/08
Data Request Deadline.......................... 04/11/08
Answers to Motions to Strike................... 04/18/08
Data Response Deadline......................... 04/18/08
Litigants file Rebuttal........................ 05/05/08
Close of Participant Comments.................. 05/05/08
Clarification.................................. 05/12/08-05/14/08
Motions to Strike.............................. 05/15/08
Data Request Deadline.......................... 05/15/08
Answers to Motions to Strike................... 05/22/08
Data Response Deadline......................... 05/22/08
Cross-Examination.............................. 05/27/08-05/30/08
Initial Briefs Filed........................... 06/09/08
Oral Argument.................................. 06/16/08-06/17/08
Publish Draft ROD.............................. 07/16/08
Briefs on Exceptions........................... 07/28/08
Publish Final ROD--Final Studies............... 08/18/08
As noted above, BPA will conduct two public field hearings in the
Pacific Northwest. Public field hearings are an opportunity for persons
who are not parties in the formal rate hearing to have their views
included in the official record. Written transcripts will be made at
all of the field hearings. The field hearings have been scheduled to
take place at the locations, dates, and times specified below. The
hearing dates also will be posted on the BPA's Web site (https://
www.bpa.gov/corporate/ratecase) and through announcements in local
newspapers. Any changes to the scheduled public hearings will be
available on the rate case Web site. The BPA Public Affairs Office also
may be contacted for this information at the telephone number
previously listed.
[[Page 7542]]
Public Field Hearings Schedule
------------------------------------------------------------------------
------------------------------------------------------------------------
03/18/08............... 6 p.m............... Spokane, Washington.
03/20/08............... 6 p.m............... Portland, Oregon.
------------------------------------------------------------------------
Part II--Policy Guidance and Scope of Hearing
A. Policy Guidance
The following policies are foundational elements that guided the
development of major components of this supplemental rate proposal.
1. BPA's Subscription Strategy
On December 21, 1998, BPA issued a Power Subscription Strategy and
Record of Decision (Subscription Strategy). The Subscription Strategy
reflected BPA's position on the equitable distribution of Federal power
for FY 2002-2011. The Subscription Strategy was the culmination of a
multi-year public process that established BPA's plan for the
availability of Federal power post-2001, the products from which
customers could choose, and an outline of the contracts and pricing
framework for those products.
The Subscription Strategy provided a marketing framework for the
WP-02 and WP-07 power rate cases. The WP-02 and WP-07 power rate cases
developed the rate schedules necessary for the products and contracts
that were developed through Subscription. The Subscription contracts,
except for the REP Settlement Agreements, continue to be the basis for
the contractual relationship between BPA and nearly all of its firm
power customers. BPA is assuming for purposes of this WP-07
Supplemental Proceeding that the IOUs, except Idaho Power Company
(Idaho Power), would have signed Residential Purchase and Sale
Agreements (RPSAs) in the fall of 2000 instead of the 2000 REP
Settlement Agreements.
2. Regional Dialogue and the Near-Term and Long-Term Policies
The Regional Dialogue process began in April 2002 when a group of
BPA's Pacific Northwest electric utility customers submitted a ``joint
customer proposal'' to BPA that addressed both near-term and long-term
contract and rate issues. Since then, BPA, the Northwest Power and
Conservation Council (Council), customers, and other interested parties
have worked on these near- and long-term issues. Considering the depth
and complexity of many of these issues, BPA concluded it was not
practical to resolve all issues before the start of the WP-07 rate
case. Therefore, BPA determined that it would address the issues in two
phases. The first phase of the Regional Dialogue, referred to as the
Near-Term Policy, addressed issues that had to be resolved in order to
replace power rates that expired in September 2006. See Bonneville
Power Administration's Policy for Power Supply Role for Fiscal Years
2007-2011 (February 2005). The issues in the second phase were
addressed in BPA's Long-Term Regional Dialogue Final Policy and Record
of Decision, which was published on July 19, 2007. The Long-Term
Regional Dialogue Final Policy is expected to be implemented through
new power sales contracts and a future rate case conducted before such
contracts go into effect in FY 2012. The Long-Term Regional Dialogue
Final Policy does not affect this WP-07 Supplemental Proceeding.
3. Service to Direct Service Industries (DSIs)
The Near-Term Policy established parameters for service to the DSIs
that were further addressed in ``Bonneville Power Administration's
Service to DSI Customers for Fiscal Years 2007-2011, Administrator's
Record of Decision'' (DSI ROD) (June 30, 2005), and Supplement to
Administrator's Record of Decision on Bonneville Power Administration's
Service to Direct Service Industrial (DSI) Customers for Fiscal Years
2007-2011, Administrator's Record of Decision (May 31, 2006), (together
the ``DSI RODs'').
In the DSI RODs, BPA determined to offer to aluminum company DSIs
power sales contracts for an aggregate 560 aMW of benefits at a capped
cost of $59 million. In addition, BPA offered a 17 aMW surplus firm
power sales contract for Port Townsend Paper Company through the local
public utility under the FPS rate (or the Industrial Firm Power (IP)
rate, if viable) at a price approximately equivalent to, but in no case
less than, its lowest-cost PF rate.
BPA decided to allocate a share of the 560 aMW of service benefits
to each DSI aluminum company for purposes of making an initial offer of
service. Because of the financial risks inherent in providing actual
power and in order to meet the known and capped cost prerequisite, BPA
determined that the delivery mechanism would be to monetize the value
of the below-market power sales to provide service benefits through
cash payments.
4. Power Function Review and Other Cost Reviews
In January 2005, BPA initiated an extensive process, known as the
Power Function Review (PFR), to examine Power Services' (formerly known
as Power Business Line or PBL) intended program spending levels. The
PFR process consisted of two phases designed to give interested parties
an opportunity to examine, understand and provide input on the cost
projections that would form the basis for BPA's WP-07 Power Rate
Proposal. The first phase concluded in June 2005 when BPA issued the
PFR Final Report. At that time, BPA committed to re-examine the program
levels prior to establishing power rates in BPA's final proposal. In
early 2006, BPA conducted the second phase, known as PFR II, allowing
interested parties an opportunity to review these program levels.
Workshops were held during January through March, 2006 and in April of
2006, BPA issued a draft closeout report for comment. After the close
of comment, BPA reviewed all comments and issued the PFR II Final
Closeout Report documenting BPA's decisions on June 1, 2006. These
updated program levels were then incorporated into BPA's WP-07 Final
Proposal.
5. Mid-WP-07 Rate Period Cost Forecast Changes
For the WP-07 Supplemental Proceeding, BPA reviewed the FY 2009
program levels incorporated into the WP-07 Final Proposal that were
developed through the PFR I and II processes. BPA then evaluated
whether these forecasts remain reasonable in light of current
projections. From this evaluation, BPA determined that adjustments were
needed in certain program areas to address significant changes in
forecast program levels. Specifically, these cost areas include: The
Residential Exchange Program; Columbia Generating Station (CGS)
operation and maintenance; interest; amortization; depreciation;
renewables; energy efficiency; long-term generating projects;
augmentation; purchased power; and fish and wildlife costs. BPA
described the nature of the non-REP cost changes to interested persons
in a public workshop on October 10, 2007.
In the October workshop, BPA notified attendees that it intended to
initiate a separate public process to address possible changes to the
fish and wildlife cost forecast for FY 2009, \1\ costs of operating the
CGS, and other cost changes identified that are relevant to the WP-07
Supplemental Proceeding. In
[[Page 7543]]
this separate forum, BPA will provide interested persons an opportunity
to review and comment on any adjustments to program levels. After the
close of comment, BPA will issue a closeout report detailing any
necessary adjustments to program levels. These forecast costs will then
be incorporated into BPA's final rate proposal for FY 2009.
---------------------------------------------------------------------------
\1\ Such changes could result from, for example, the issuance by
NOAA Fisheries of a final Biological Opinion regarding the impacts
of the mainstem Federal Columbia River Power System dams on
threatened and endangered salmon and steelhead, and from any related
commitments BPA may make in a long-term Memoranda of Agreement
currently being discussed with some regional governmental entities.
---------------------------------------------------------------------------
6. Post-2006 Conservation Program Structure Proposal
The Conservation Program Structure Proposal was finalized and
issued June 28, 2005. It describes BPA's approach to offering
conservation programs during FY 2007 through FY 2009. The decisions of
this post-2006 proposal were used as inputs in the development of BPA's
WP-07 Power Rate Case Final Proposal. BPA does not propose any changes
in this area for the WP-07 Supplemental Proceeding.
7. Transmission Rate Case
BPA is committed to marketing its power and transmission services
separately in a manner modeled after the regulatory initiatives adopted
in 1996 by FERC to promote competition in wholesale power markets.
FERC's initiatives in Orders 888 \2\ and 889 \3\ directed public
utilities regulated under the Federal Power Act to separate their power
merchant functions from their transmission reliability functions;
unbundle transmission and ancillary services from wholesale power
services; and set separate rates for wholesale generation,
transmission, and ancillary services. Although BPA is not required by
law to follow FERC's regulatory directives that promote competition and
open access transmission service, BPA elected to separate its power and
transmission operations and unbundle its rates in a manner consistent
with the directives concerning open access transmission service. BPA
develops its transmission rates in separate proceedings from its power
rates.
---------------------------------------------------------------------------
\2\ Promoting Wholesale Competition Through Open Access Non-
Discriminatory Transmission Services by Public Utilities; Recovery
of Stranded Costs by Public Utilities and Transmitting Utilities
Reg-Preamble, FERC Stats & Regs 1991-96, para. 31,036 (1996).
\3\ Open Access Same-Time Information System (formerly Real-Time
Information Networks) and Standards of Conduct, Reg-Preamble, FERC
Stats & Regs 1991-96, para. 31,035 (1996).
---------------------------------------------------------------------------
On February 5, 2007, BPA's Transmission Services (formerly known as
the Transmission Business Line or TBL) initiated a rate case to
establish transmission rates for the FY 2008-2009 transmission rate
period. Prior to the initiation of that rate case, Transmission
Services held several public meetings with customers from July through
November 2006 to discuss transmission costs, revenues, and rate design
issues for the FY 2008-2009 rate period. Customers expressed interest
in meeting with Transmission Services to develop a settlement for the
FY 2008-2009 rate period. Transmission Services continued meetings with
customers between October and November 2006, resulting in the 2008
Transmission Rate Case Settlement Agreement.
On April 23, 2007, BPA issued the ``Final Transmission Rate
Proposal Administrator's Record of Decision'' which adopted the
transmission and ancillary services rates reflected in the 2008
Transmission Rate Case Settlement Agreement. FERC granted interim
approval to these rates on September 20, 2007. The Transmission
Services rate case settlement established fixed rates for certain
ancillary services and some transmission rates that incorporate
ancillary services. The generation inputs that support the ancillary
services and other control area services sold by Transmission Services
are provided by Power Services. BPA is not proposing any changes to its
generation input costs for FY 2009 except for the recognition of
additional revenues expected from Transmission Services for Wind
Integration.
B. Scope of the WP-07 Supplemental Proceeding
Many of the policies that guide BPA's power marketing decisions
have been made or will be made in other public review processes. In
addition, many decisions about BPA's financial commitments, including
for example, what BPA plans to spend on meeting its fish and wildlife
obligations, are made in forums other than the rate case. This section
provides guidance to the Hearing Officer as to those matters that are
within the scope of the rate case, and those that are outside the
scope.
1. Program Level Expense Forecasts and Commitments
Section 7(i) rate proceedings establish the rates applicable to
BPA's products and services at levels set to assure recovery of BPA's
costs in total. The section 7(i) proceeding does not establish the
program levels to be recovered during a rate period. Instead, program
levels (including programmatic decisions and decisions regarding
spending commitments) are decided in various forums outside the section
7(i) proceedings. Once set, however, program levels are taken into
consideration when designing the rates proposed in a section 7(i)
proceeding to ensure such costs are recovered. As described in Part
II.A.5, BPA evaluated whether updated forecasts of program levels were
needed for this WP-07 Supplemental Proceeding, and determined that,
except in a few instances, they were not. Therefore, except as noted
above in Part II.A.5 and described below, this WP-07 Supplemental
Proceeding will not revisit the previous forecasts of program levels
for FY 2007-2009 made in the PFR I and II processes and incorporated
into the WP-07 Final Proposal. Nor is this WP-07 Supplemental
Proceeding the forum to revisit or seek new decisions regarding program
spending commitments for this period.
To allow public review and input on program level forecasts that
BPA has determined require updating, BPA will hold a separate process
to address adjustments to the program level forecasts for FY 2009
associated with CGS costs, fish and wildlife costs and any other
necessary program categories for which significant changes have or may
occur before BPA's final rate proposal. This separate process will
include an opportunity for entities, such as fish and wildlife
managers, to engage BPA on the cost assumptions made and the
appropriateness of any proposed adjustments in forecasts. Any
adjustments adopted by BPA to the program level forecasts for FY 2009
as a result of this separate process will be incorporated into BPA's
final rate proposal for FY 2009. Because discussions regarding spending
commitments or discussions about adjustments in forecasts of costs in
these program areas will occur in forums separate from this rate
proceeding, pursuant to Sec. 1010.3(f) of BPA Hearing Procedures, the
Administrator hereby directs the Hearing Officer to exclude from the
record any materials attempted to be submitted or arguments attempted
to be made in the proceeding that seek to address program spending
commitment decisions, or address adjustments in the program level
forecasts for FY 2009 for CGS costs, fish and wildlife costs, and any
other program categories.
2. Near-Term Policy Decisions
As detailed above, BPA issued the Near-Term Policy on February 4,
2005. The Policy resolved a number of policy decisions that affect
BPA's WP-07 Supplemental Proposal. Those issues include, but are not
limited to, decisions on the availability of the lowest cost PF rate to
public agency customers; the term of the rate period; DSI service
options; and the availability of products for new or existing
customers. Pursuant to Sec. 1010.3(f) of the BPA Hearing
[[Page 7544]]
Procedures, the Administrator hereby directs the Hearing Officer to
exclude from the record any materials attempted to be submitted or
arguments attempted to be made in the proceeding that seek to in any
way to revisit the appropriateness or reasonableness of BPA's decisions
made in the Near-Term Policy ROD.
3. DSI Service
The DSI Service RODs established the manner in which BPA would
provide service and benefits to its DSI customers during FY 2007-2011.
Pursuant to Sec. 1010.3(f) of the BPA Hearing Procedures, the
Administrator directs the Hearing Officer to exclude from the record
any materials attempted to be submitted or arguments attempted to be
made in the proceeding that seek to in any way to revisit the
appropriateness or reasonableness of BPA's decisions made in the DSI
RODs.
4. Transmission Acquisition Expense
In the PFR I and II processes, BPA reviewed with interested persons
program levels related to Power Services' transmission acquisitions.
These program levels represent the costs associated with services
necessary to deliver energy from generating resources to markets and
loads. These costs include: transmission expenses; ancillary services;
real power losses; generation integration costs associated with BPA-
owned transmission facilities; and metering and communication
requirements. Pursuant to Sec. 1010.3(f) of BPA Hearing Procedures,
the Administrator hereby directs the Hearing Officer to exclude from
the record any materials attempted to be submitted or arguments
attempted to be made in the hearing that seek to in any way revisit the
appropriateness or reasonableness of BPA's transmission acquisition
program level estimates.
5. Other Transmission Issues
a. Generation Inputs
Power Services provides a portion of the FCRPS's available
generation to Transmission Services to enable Transmission Services to
meet its various transmission and control area requirements.
Transmission Services uses the generation inputs to provide ancillary
and control area services. To recover the costs associated with
providing these generation inputs, Power Services develops charges
based on relevant FCRPS costs that are assessed the transmission
function. The costs Power Services are proposing to use to determine
the generation input costs and associated unit costs to Transmission
Services were addressed in the BPA's WP-07 Final Proposal. Based on
updated information, the WP-07 Supplemental Proposal will include
revised charges for some generation inputs and these revisions are
included within the scope of this rate proceeding. Pursuant to Sec.
1010.3(f) of BPA's Hearing Procedures, the Administrator directs the
Hearing Officer to exclude from the record any materials attempted to
be submitted or arguments attempted to be made in the proceeding that
seek in any way to revisit the appropriateness or reasonableness of any
issues, other than the charges, related to the generation inputs. This
exclusion includes, but is not limited to, issues regarding the level
or quality of the generation inputs that Transmission Services requests
from Power Services. These determinations are generally made by
Transmission Services in accordance with industry, reliability, and
other compliance standards and criteria, and are not matters
appropriate for the WP-07 Supplemental Proceeding.
In addition, BPA will conduct a section 7(i) process related to
within-hour balancing capacity for wind generation. Pursuant to Sec.
1010.3(f) of BPA's Hearing Procedures, the Administrator directs the
Hearing Officer to exclude from the record any materials attempted to
be submitted or arguments attempted to be made in the WP-07
Supplemental Proceeding that seek in any way to address the issues
contained within the scope of the within-hour balancing capacity for
wind generation rate proceeding (Proposed Wind Integration--Within-Hour
Balancing Service Rate (WI-09)), except that the appropriate treatment
of the additional revenue resulting from this proceeding is a matter
that is included within the scope of the WP-07 Supplemental Proceeding.
b. Transmission Rate Case
On April 23, 2007, BPA issued the 2008 ``Final Transmission
Proposal-Administrator's Record of Decision'' that adopted the
transmission and ancillary services rates as reflected in the 2008
Transmission Rate Case Settlement Agreement. FERC granted interim
approval to these transmission rates on September 20, 2007. Pursuant to
Sec. 1010.3(f) of BPA Hearing Procedures, the Administrator hereby
directs the Hearing Officer to exclude from the record any materials
attempted to be submitted or arguments attempted to be made in the
hearing which seek in any way to revisit the appropriateness or
reasonableness of issues determined in the transmission rate case. That
proceeding addressed, among other things, transmission and ancillary
service rate levels, redispatch costs between Transmission Services and
Power Services related to Attachment K redispatch for FY 2008-2009, and
the level of the GTA Delivery Charge for FY 2009.
6. Post-2006 Conservation Program Structure Proposal
Through the post-2006 workgroup collaboration, customers and
constituents provided input on the development of BPA's post-2006
conservation approach. Pursuant to Sec. 1010.3(f) of BPA Hearing
Procedures, the Administrator hereby directs the Hearing Officer to
exclude from the record any materials attempted to be submitted or
arguments attempted to be made in the hearing that seek to in any way
revisit the appropriateness or reasonableness of BPA's conservation
programs and establishment of their associated expense levels through
the Post-2006 Conservation Program Structure Proposal dated June 28,
2005. The Hearing Officer is also directed to exclude from the scope of
this proceeding evidence regarding BPA's portfolio of conservation
programs, as well as their expenses, that BPA intends to pursue during
FY 2009.
7. Federal and Non-Federal Debt Service and Debt Management
During the PFR, and in other forums, BPA has provided background
information on its internal Federal and non-Federal debt management
policies and practices. The discussions of these topics in the PFR and
other forums were not intended to seek input from customers and
constituents regarding BPA's debt management policies and practices.
Rather, these discussions were intended to merely inform interested
parties about these matters so that they would better understand BPA's
debt structure. Although the PFR closeout letter did not make any
decisions regarding BPA's debt management policies and practices, these
remain outside the scope of the rate case. Therefore, pursuant to Sec.
1010.3(f) of BPA Hearing Procedures, the Administrator hereby directs
the Hearing Officer to exclude from the record any materials attempted
to be submitted or arguments attempted to be made in the hearing which
seek to in any way visit the appropriateness or reasonableness of BPA's
debt management policies and practices.
8. Average System Cost Methodology
Concurrent with the publication of this notice, BPA is publishing a
separate notice in the Federal Register to commence a consultation
proceeding to
[[Page 7545]]
develop a new Average System Cost (ASC) Methodology. Section 5(c) of
the Northwest Power Act established the REP, which provides benefits to
residential consumers of Pacific Northwest utilities based, in part, on
a utility's ``average system cost'' of resources. Section 5(c)(7) of
the Act authorizes the Administrator to consult with regional interests
to develop an ASC methodology. The ASC Methodology prescribes which
costs are included and excluded from a utility's ASC, as well as the
procedural rules for filing proposed ASCs with BPA. Comments on BPA's
proposed ASC Methodology will be submitted, reviewed and addressed
solely in the separate consultation proceeding. For this reason, issues
related to the proposed ASC Methodology are not within the scope of
this proceeding. Therefore, pursuant to Sec. 1010.3(f) of BPA Hearing
Procedures, the Administrator hereby directs the Hearing Officer to
exclude from the record any materials attempted to be submitted or
arguments attempted to be made in the hearing that seek to in any way
visit the appropriateness or reasonableness of the proposed ASC
Methodology.
9. Potential Environmental Impacts
For the reasons stated in Section C below, the Administrator
directs the Hearing Officer to exclude from the record all evidence and
arguments that seek in any way to address the potential environmental
impacts of the rates being developed in the WP-07 Supplemental
Proceeding. Any such evidence and arguments submitted will be
considered and addressed in the separate, concurrent process described
in the next section.
C. The National Environmental Policy Act
BPA is in the process of assessing the potential environmental
effects of its WP-07 Supplemental Proposal, consistent with the
National Environmental Policy Act (NEPA). BPA's Business Plan
Environmental Impact Statement (Business Plan EIS), completed in June
1995, evaluated the environmental impacts of a range of business plan
alternatives that could be varied by applying 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
addressed response strategies, including adjusting rates, that BPA
could pursue if BPA's costs exceeded its revenues. In August 1995, the
BPA Administrator issued a Record of Decision (Business Plan ROD) that
adopted the Market-Driven 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 Supplemental
Analysis to the Business Plan EIS. The Supplemental Analysis found that
the Business Plan EIS's relationship-based and policy-level analysis of
potential environmental impacts from BPA's business practices remains
valid, and that BPA's current business practices are still consistent
with BPA's Market-Driven 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.
Because the WP-07 Supplemental Proposal 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 significantly
different environmental impacts from those examined in the Business
Plan EIS. Therefore, BPA expects that this WP-07 Supplemental Proposal
will 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 Supplemental ROD that will be
prepared for the FY 2007 Supplemental Wholesale Power Rate Proposal,
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. During the public review and
comment period for the WP-07 Supplemental Proposal, persons interested
in submitting comments regarding its potential environmental effects
may do so by submitting comments 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
identified in Part I will be considered by BPA's NEPA compliance staff
in the NEPA process that will be conducted for this Proposal.
Part III--Public Participation
A. Distinguishing Between ``Participants'' and ``Parties''
BPA distinguishes between ``participants in'' and ``parties to''
the section 7(i) hearing process. Apart from the formal hearing
process, BPA will accept comments, views, opinions, and information
from ``participants,'' who are defined in the BPA Hearing Procedures as
persons who may submit comments without being subject to the duties of,
or having the privileges of, parties. Participants' written and oral
comments will be made a part of the official record and considered by
the Administrator when making his decision. 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.
The views of participants are important to BPA. Written comments by
participants will be included in the record if they are received by
5:00 p.m., Pacific Daylight Savings Time, on May 5, 2008. This date
follows the anticipated submission of BPA's and all other parties'
direct cases. Written views, supporting information, questions, and
arguments should be submitted to BPA Public Affairs at the address
listed in Paragraph 2 of the Summary. In addition, BPA will hold two
field hearings in the Pacific Northwest region. Participants may appear
at the field hearings and present verbal and written comments. The
transcripts of these hearings will be part of the record upon which the
Administrator makes his final rate decisions.
Persons who previously intervened in BPA's 2007 Wholesale Power
Rate Adjustment Proceeding automatically continue their party status in
the 2007 Supplemental Proceeding. Other persons wishing to become a
party to BPA's rate proceeding must notify BPA in writing and file a
Petition to Intervene with the Hearing Officer. Petitioners may
designate no more than two representatives upon whom service of
documents will be made. Petitions to Intervene must state the name and
address of the person requesting party status and the person's interest
in the hearing.
Petitions to Intervene as parties in the rate proceeding are due to
the Hearing
[[Page 7546]]
Officer by 5 p.m., Pacific Standard Time, on February 18, 2008. The
petitions should be directed as stated below or may be e-mailed to
wp07rate@bpa.gov: Robert Welsh, Hearing Clerk-LP-7, Bonneville Power
Administration, 905 NE 11th Avenue, P.O. Box 3621, Portland, OR 97208-
3621.
Petitioners must explain their interests in sufficient detail to
permit the Hearing Officer to determine whether they have a relevant
interest in the proceeding. Pursuant to Sec. 1010.1(d) of BPA Hearing
Procedures, BPA waives the requirement in Sec. 1010.4(d) that an
opposition to an intervention petition must be filed and served 24
hours before the February 19, 2008, prehearing conference. Any
opposition to an intervention petition may instead be made at the
prehearing conference. Any party, including BPA, may oppose a petition
for intervention. Persons who have been denied party status in any past
BPA rate proceeding shall continue to be denied party status unless
they establish a significant change of circumstances. All timely
applications will be ruled on by the Hearing Officer. Late
interventions are strongly disfavored.
B. Developing the Record
The record will comprise, among other things, verbal and written
comments made by participants, including the transcripts of all
hearings, any written materials submitted by the parties, documents
developed by BPA staff, and other materials accepted into the record by
the Hearing Officer. Written comments by participants will be included
in the record if they are received by 5 p.m., Pacific Daylight Savings
Time, on May 5, 2008. The Hearing Officer will then review the record,
supplement it if necessary, and will certify the record to the
Administrator for decision.
The Administrator will develop final proposed rates for FY 2009
based on the entire record, which includes the record certified by the
Hearing Officer, as described above. The basis for the final proposed
rates first will be expressed in the Administrator's Draft Supplemental
ROD. Parties will have an opportunity to respond to the Draft
Supplemental ROD as provided in the BPA Hearing Procedures. The
Administrator will serve copies of the Final Supplemental ROD on all
parties. At the conclusion of the rate proceeding, BPA will file the
supplemental rate case record and rates for FY 2009 in a timely manner
to receive FERC confirmation and approval effective October 1, 2008.
BPA must continue to meet with customers in the ordinary course of
business during the rate case. To comport with the rate case procedural
rule prohibiting ex parte communications, BPA will provide the
prescribed notice of meetings involving rate case issues in order to
permit the opportunity for participation by all rate case parties.
These meetings may be held on very short notice. Consequently, parties
should be prepared to devote the necessary resources to participate
fully in every aspect of the rate proceeding and attend meetings any
day during the course of the rate case.
Part IV--Summary of WP-07 Supplemental Proposal and Major Studies
A. Summary of Proposed 2009 Wholesale Power Rate Structure
1. List of Proposed 2009 Wholesale Power Rates
BPA is proposing to revise several rate schedules for its 2007
Supplemental Wholesale Power Rates to respond to the Court's recent
opinions. The rate schedules and the GRSPs are available for viewing
and downloading on BPA's Web site at https://www.bpa.gov/corporate/
ratecase as discussed in Part VII of this Notice.
a. PF-07R Priority Firm Power Rate
The PF rate schedule is comprised of two rates: the PF Preference
rate and the PF Exchange rate.
The PF Preference rate applies to BPA's firm power sales to public
bodies, cooperatives, and Federal agencies for resale to their regional
consumers. This power is guaranteed to be continuously available. The
proposed average PF Preference rate is $26.2/MWh. The rate applies to
the following products:
Full Service Product
Actual Partial Service Product--Simple
Actual Partial Service Product--Complex
Block Product
Block Product with Factoring
Block Product with Shaping Capacity
Slice Product
The PF Exchange rate applies to sales of power to regional
utilities that participate in the Residential Exchange Program
established under section 5(c) of the Northwest Power Act. 16 U.S.C.
839c(c). BPA is proposing to revise the PF Exchange rate to remove the
demand and energy rates and substitute a single annual rate. In
addition, BPA is proposing to include utility-specific supplemental
rate charges, consistent with section 7(b)(3) of the Northwest Power
Act. 16 U.S.C. 839e(b)(3). These PF Exchange rates are used in
determining REP benefits in FY 2009.
b. NR-07R New Resource Firm Power Rate
The New Resource Firm Power (NR) rate applies to net requirements
power sales to IOUs for resale to ultimate consumers for direct
consumption, construction, test and start-up, and for station service.
NR-07R firm power is also available to public utility customers for
serving New Large Single Loads. This rate applies to the following
products:
New Large Single Loads
Full Service Product
Actual Partial Service Product--Simple
Actual Partial Service Product--Complex
Block Product
Block Product with Factoring
Block Product with Shaping Capacity
c. IP-07R Industrial Firm Power Rate
The IP rate is available for discretionary 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).
d. FPS-07R Firm Power Products and Services Rate
The FPS rate schedule is available for the purchase of Firm Power,
Capacity Without Energy, Supplemental Control Area Services, Shaping
Services, and Reservation and Rights to Change Services for use inside
and outside the Pacific Northwest. The rates for these products are
posted and/or negotiated. BPA is proposing only minor changes to this
rate schedule for FY 2009.
e. GTA-07R General Transfer Agreement Delivery Charge
The GTA Delivery Charge applies to customers who purchase Federal
power that is delivered over non-Federal low voltage transmission
facilities. This rate was originally set in the 2006 Transmission
Services Rate Case Settlement to mirror the Utility Delivery rate from
October 1, 2005, through September 30, 2007. BPA's 2007 Power Rate Case
determined that the GTA Delivery Charge would continue to mirror the
Utility Delivery rate, which is $1.119 per kilowatt through September
30, 2009. For FY 2009, Power Services is proposing to continue to set
the GTA Delivery Charge to the same rate as Transmission Services'
posted monthly Utility Delivery rate, which is $1.119 per kilowatt.
[[Page 7547]]
2. Significant Rate Development Issues
a. Residential Exchange Program Costs
For FY 2009, BPA expects qualifying regional utilities to
participate in the REP. BPA is concurrently developing a new ASC
Methodology in a separate proceeding and will be offering new RPSAs to
requesting utilities. In order to include the costs of an REP in BPA's
FY 2009 rates, BPA is forecasting the ASCs of utilities expected to
participate in the program. In addition, BPA is forecasting the
expected utilities' system and exchangeable residential and small farm
loads. However, the ASC Methodology being revised in a concurrent
process will be used to conduct an expedited review of utilities' ASCs
outside of this WP-07 Supplemental Proceeding. This review will
determine the actual ASCs for eligible utilities for FY 2009. Those ASC
determinations, when complete, will be incorporated into the final rate
proposal and used to determine REP costs in FY 2009 rates.
b. Inter-Function Costs and Credits
BPA is not proposing any changes to its inter-function generation
input unit charges for FY 2009. The forecast of revenues for FY 2009 in
the WP-07 Final Proposal will continue to be used. However, BPA will
adjust the inter-function revenue credit to reflect the additional
revenues that Power Services expects to receive from Transmission
Services based on the proposed Wind Integration--Within-Hour Balancing
Service Rate Proceeding (WI-09). Therefore, BPA is proposing to
incorporate the forecast revenues determined in the Wind Integration
rate case into the final rates of this proceeding.
c. DSI Service FY 2007-2011
BPA continues to forecast no direct service sales under the IP rate
to its DSI customers. Instead, BPA provides the DSI aluminum smelters
560 aMW of surplus firm power service benefits for the FY 2007-2011
period at a capped cost of $59 million per year. Benefits have been
monetized under the contacts with these companies. In addition, BPA
provides a 17 aMW surplus firm power sales contract for Port Townsend
Paper Company through the local public utility under the FPS rate
schedule at a rate that is approximately equivalent to BPA's lowest-
cost PF rate.
3. Rate Design and Rate Adjustments
Consistent with the Partial Resolution of Issues negotiated between
BPA and rate case parties before the WP-07 Final Proposal, BPA is
generally continuing its existing WP-07 rate design for its FY 2009
rates, with only minor modifications listed below. In addition, BPA is
generally continuing its existing set of rate adjustments for its FY
2009 rates, also described below.
a. Conservation Rate Credit (CRC)
BPA is not proposing any changes from its WP-07 Final Proposal for
the CRC.
b. Risk Mitigation Tools
Other than resetting the cap for the FY 2009 Cost Recovery
Adjustment Clause (CRAC) and the thresholds for the FY 2009 CRAC and
Dividend Distribution Clause (DDC), BPA is proposing no other changes
to the CRAC or DDC in the WP-07 Supplemental Proposal. BPA will use the
same technical methodology to assess risks and intends to employ the
same risk mitigation measures as presented in the WP-07 Final \4\
Proposal.
---------------------------------------------------------------------------
\4\ Accumulated Modified Net Revenue
Table 1.--CRAC Cap and CRAC and DDC Annual Thresholds for FY 2009
[Millions of dollars]
----------------------------------------------------------------------------------------------------------------
Approx.
AMNR threshold as
calculated at CRAC or DDC CRAC or DDC measured in Maximum CRAC
end of fiscal applied to threshold in power recovery
year fiscal year AMNR \4\ services' amount (cap)
reserves
----------------------------------------------------------------------------------------------------------------
CRAC........................... 2008 2009 ($81.4) $750 $36
DDC............................ 2008 2009 218.6 1,050 n/a
----------------------------------------------------------------------------------------------------------------
BPA proposes to continue the National Marine Fisheries Service
(NMFS) Federal FCRPS Biological Opinion (NFB) Adjustment and the
Emergency NFB Surcharge. Although BPA expects to include the forecast
cost of implementing the final Biological Opinion for the FCRPS in its
final supplemental rates, litigation regarding the Biological Opinion
may continue, so the Emergency NFB Surcharge and the NFB Adjustment
remain appropriate. In order to balance the need to cover risk with
overall rate levels, BPA proposes to meet its Treasury Payment
Probability (TPP) standard through a combination of financial reserves,
the CRAC, the NFB Adjustment, the Emergency NFB Surcharge, and the
Flexible PF Rate Program. See Part IV.A.4.
c. Excess Factoring Charge
This is a charge that applies to purchasers of the Complex Actual
Partial Service Product under the PF rate schedule. BPA is proposing no
changes to this charge as established in the WP-07 Final Proposal.
d. Green Energy Premium (GEP)
BPA is proposing no changes to the GEP in this Supplemental
Proposal. The proposed GEP continues to range from zero to 40 mills per
kWh depending on the specific products and associated costs selected by
each customer. BPA forecasts an average of $3 million of annual revenue
from the GEP for FY 2009, which is an increase from the WP-07 Final
Proposal. A portion of revenues from the GEP will support BPA's
renewable-related research, development and demonstration projects.
e. Load Variance Charge
Except for a change in its level, consistent with the Partial
Resolution of Issues, BPA is proposing no other changes to the Load
Variance Charge. This proposed charge of $0.45/MWh covers BPA's cost of
meeting customers' load growth for reasons other than annexation or
retail access load gain or loss. In addition, it provides Full and
Partial Service purchasers the right to deviate from their monthly
forecast of BPA purchases due to weather, economic business cycles,
plant energy consumptions and other reasons.
f. Low Density Discount (LDD)
BPA is proposing no changes to the LDD as established in the WP-07
Final
[[Page 7548]]
Proposal and as agreed to in the Partial Resolution of Issues.
g. Monthly Demand and Energy Charges
BPA is proposing no changes to the methodology for calculating
demand and energy charges. There will be two diurnal periods, Heavy
Load Hour (HLH) and Light Load Hours (LLH), for each month. BPA
continues to adopt slight changes to the definitions of HLH and LLH to
be consistent with NERC definitions. The proposed demand and energy
charges will be updated consistent with the Partial Resolution of
Issues.
h. PF Targeted Adjustment Charge (PF TAC)
BPA is proposing no changes to the Targeted Adjustment Charge from
that established in the WP-07 Final Proposal.
i. Unauthorized Increase Charges (UAI) for Power Sales
These are penalty charges for Unauthorized Increases in Energy and
Unauthorized Increases in Demand for deliveries that exceed contractual
entitlements for energy and demand, respectively. BPA is proposing no
changes relative to the WP-07 Final Proposal.
j. Demand Adjuster
This is an adjustment that is made to the demand billing factor for
certain requirements products. BPA is proposing no changes relative to
the WP-07 Final Proposal.
k. Flexible PF and NR
These are rate options available, at BPA's discretion, to
purchasers under the PF and NR rate schedules. BPA is proposing no
chan