Electric Energy Market Competition Task Force; Notice Requesting Comments on Wholesale and Retail Electricity Competition, 60819-60822 [05-20896]
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Federal Register / Vol. 70, No. 201 / Wednesday, October 19, 2005 / Notices
60819
897TH—MEETING, REGULAR MEETING, OCTOBER 20, 2005, 10 A.M.—Continued
Item No.
Docket No.
C–6 ...........................
C–7 ...........................
CP04–365–001 .....................................
CP04–34–001 .......................................
Magalie R. Salas,
Secretary.
The Capitol Connection offers the
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Immediately following the conclusion
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[FR Doc. 05–21013 Filed 10–17–05; 2:05 pm]
BILLING CODE 6717–01–P
DEPARTMENT OF ENERGY
Federal Energy Regulatory
Commission
[Project No. 12533–001]
Christopher James Phil; Notice of
Surrender of Preliminary Permit
October 12, 2005.
Take notice that Christopher James
Phil, permittee for the proposed May
Creek Project, has requested that its
preliminary permit be terminated. The
permit was issued on March 8, 2005,
and would have expired on February 29,
2008.1 The project would have been
located on May Creek and Lake Isabel in
Snohomish County, Washington.
The permittee filed the request on
September 26, 2005, and the
preliminary permit for Project No.
12533 shall remain in effect through the
thirtieth day after issuance of this notice
unless that day is a Saturday, Sunday,
part-day holiday that affects the
Commission, or legal holiday as
described in section 18 CFR 385.2007,
1 110
FERC ¶ 62,227 (2005).
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Company
Dominion Transmission, Inc.
Columbia Gas Transmission Corporation.
in which case the effective date is the
first business day following that day.
New applications involving this project
site, to the extent provided for under 18
CFR Part 4, may be filed on the next
business day.
Magalie R. Salas,
Secretary.
[FR Doc. E5–5763 Filed 10–18–05; 8:45 am]
BILLING CODE 6717–01–P
DEPARTMENT OF ENERGY
Federal Energy Regulatory
Commission
[Docket No. AD05–17–000]
Electric Energy Market Competition
Task Force; Notice Requesting
Comments on Wholesale and Retail
Electricity Competition
October 13, 2005.
Overview
Section 1815 of the Energy Policy Act
of 2005 requires the Electric Energy
Market Competition Task Force to
conduct a study of competition in
wholesale and retail markets for electric
energy in the United States. Over the
past several years, wholesale
competition has developed unevenly in
many regions of the country. Moreover,
fewer than 20 States have adopted retail
choice programs that allow some
electricity consumers to choose their
retail electric generation supplier. The
purpose of this study is to analyze and
report to Congress on the critical
elements for effective wholesale and
retail competition, the status of each
element, impediments to realizing each
element, and suggestions for
overcoming these impediments.
In recent years, some states and the
Federal government have taken steps to
encourage competition in the electric
power industry. In the Energy Policy
Act of 2005, Congress established an
inter-agency task force, known as the
‘‘Electric Energy Market Competition
Task Force’’ (the Task Force), to conduct
a study and analysis of competition
within the wholesale markets and retail
markets for electric energy in the United
States. The Task Force consists of 5
members:
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(1) 1 employee of the Department of
Justice, appointed by the Attorney
General of the United States—J. Bruce
McDonald, Deputy Assistant Attorney
General, Antitrust Division; (202) 514–
1157, bruce.mcdonald@usdoj.gov.
(2) 1 employee of the Federal Energy
Regulatory Commission, appointed by
the Chairperson of that Commission—
Michael Bardee, Associate General
Counsel, Office of the General CounselMarkets, Tariffs, and Rates; (202) 502–
8068, michael.bardee@ferc.gov.
(3) 1 employee of the Federal Trade
Commission, appointed by the
Chairperson of that Commission—
Michael Wroblewski, Assistant General
Counsel for Policy Studies; (202) 326–
2166, mwroblewski@ftc.gov.
(4) 1 employee of the Department of
Energy, appointed by the Secretary of
Energy—David Meyer, Deputy Director,
Division of Permitting, Siting, and
Analysis, Office of Electricity Delivery
and Energy Reliability; (202) 586–1411,
David.Meyer@hq.doe.gov.
(5) 1 employee of the Rural Utilities
Service, appointed by the Secretary of
Agriculture—Karen Larsen, Office of
Assistant Administrator, Electric
Programs (202) 720–9545,
Karen.Larsen@usda.gov.
Section 1815(c) of the Energy Policy
Act of 2005 requires the Task Force to
‘‘consult with and solicit comments
from any advisory entity of the task
force, the States, representatives of the
electric power industry, and the
public.’’ This Notice begins this process.
The Task Force also will publish a draft
final report for public comment, before
submitting the final version to Congress
as required by Section 1815(b)(2)(B).
Listed below is a series of questions
for which the Task Force seeks public
comment. For both wholesale and retail
competition for electric power, we focus
on the current state of competition and
on factors that help support
competition, or that otherwise may limit
competition, among suppliers and
buyers in regional wholesale markets
and retail markets at the state level. The
questions listed below are by no means
exhaustive. The Task Force encourages
commentors to raise any other
additional factors that affect
competition in wholesale and retail
electric power markets. It is not
necessary to respond to each question.
Rather, it would be helpful for
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Federal Register / Vol. 70, No. 201 / Wednesday, October 19, 2005 / Notices
respondents to provide, for example,
specific information about market
responses to particular governing
regulations, or to compare and contrast
the market reaction to the means
individual states have used to address
various retail competition issues (e.g.,
generation siting, provider of last resort
pricing, etc.).
Overview Questions
1. What are the critical elements or
attributes of competition in wholesale
electricity markets that the Task Force
should examine?
2. What are the critical elements or
attributes of competition in retail
electricity markets that the Task Force
should examine?
3. What benefits have occurred
because of competition in wholesale
and retail electricity markets? What
additional benefits are expected? What
benefits were forecasted and have not
occurred? Why? What harms have
occurred because of competition in
wholesale and retail electricity markets?
4. What are the major public policy
concerns that the Task Force should
examine in its review of competition in
wholesale and retail electricity markets?
5. In what significant ways do
wholesale and retail electricity markets
differ from other energy or commodity
markets? What implications do their
differences have for public policy?
Wholesale Market Questions
Commentors should answer with a
specific regional wholesale market in
mind and should be as specific as
possible.
A. Wholesale Supply Trading and
Participation
1. To what extent does wholesale
trading help result in an economic and
reliable supply of electricity in each
region? What are ways to improve the
provision of an economic and reliable
supply of electricity?
2. What share of electric power used
to serve retail (or ultimate consumer)
load is obtained through wholesale
market transactions in each state or
region? In what ways has this share
changed over the past 10 years and the
past 5 years and why?
3. What share of electric power used
to serve ultimate consumer load is
generated by a utility for its own native
load? What share of electric power used
to serve utility customer load comes
from utility affiliates? What share comes
from unaffiliated generators?
4. What opportunities exist for
generation owners to sell output in
wholesale markets?
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5. What opportunities exist for
wholesale power buyers to purchase
electricity in wholesale markets? Is
demand (negawatts) a product that can
be traded in the wholesale market?
6. Is there an organized regional
market or exchange serving buyers and
sellers in the region? What products
does the organized market provide?
What percentage of energy supplied is
secured through organized markets and
through bilateral trades? Are there
liquid trading points in the region?
What are the volumes traded? What is
the trend of bid/ask spreads (getting
greater or smaller)?
7. To what extent do wholesale buyers
and sellers participate in futures or
others commodity markets or
transactions to balance the financial
risks of competitive electricity markets?
How liquid are forward markets in
different regions and how far ahead can
one transact in these markets?
8. What role have credit issues played
in the ability of market participants to
participate in wholesale markets,
including forward markets?
9. Are there competitive processes by
which distribution utilities solicit
proposals for native load or default
service?
10. How can changes and trends in
wholesale market prices by region be
measured?
11. How should the performance of
wholesale markets in serving the needs
of various types of power sellers (e.g.,
marketer, generator, independent
producer, merchant, public utility,
nonpublic utility, qualified facility,
renewable power producer, cogenerator) be measured?
12. How has restructuring of
incumbent utility operations and the
introduction of competitive retail
markets in retail choice states affected
participation in regional wholesale
markets? Has the introduction of retail
markets affected the level of long-term
contracting in wholesale markets?
13. Please describe instances in which
competition has resulted in relatively
higher prices or lower reliability in a
specific regional market.
B. Generation Ownership
1. How has ownership of electric
generating plants changed over the past
10 years?
2. In the past 10 years, when
generations assets have been sold or
transferred, how much capacity was
sold or transferred to (a) Utility or utility
affiliates, (b) existing non-utility market
participants; (c) new market
participants?
3. How much existing merchant or
non-utility generation assets have been
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sold or transferred? What were the
reasons for these transactions?
4. How much existing capacity has
been sold or transferred to utilities and
converted to rate-based assets? Of those
how many were previously affiliated
with a utility and how many were
purchased from other entities?
C. Generation Adequacy
1. How is generation adequacy
addressed in each region or system? Is
there a specific enforceable requirement
that load serving entities or market
participants must meet? How is
planning for generation adequacy
conducted?
2. Has new generation construction
kept pace with demand growth in the
state or market region? If not, why not?
What are the most important factors that
affect whether generation will be built?
3. What role does the ability to enter
into long-term contracts play in
financing new generation projects?
4. What generation facilities have
been installed in the past five years?
What was the experience in the process?
5. What generation facilities have
been cancelled in the past five years and
why?
6. What difficulties, if any, have
developers of new generation facilities
encountered in bringing generation
supply to market? (E.g., difficulties in
financing, siting, permitting, licensing,
interconnection, transmission access,
fuel supply.) What are ways to improve
the process?
7. Are there instances in the past five
years in which a new generation facility
has been completed that caused prices
in a previously congested area to
decline?
8. How do the approaches and
responsibilities for assuring the
availability of sufficient generation
capacity to meet peak load and load
growth vary among regions and states
that have retail choice and/or tightly
organized regional markets and those
that do not?
9. What incentives do competitive
suppliers have to maintain adequate
reserve capacity?
10. What incentives or responsibilities
do load serving utilities have to
maintain adequate reserve capacity?
11. How can competitive markets
assure adequacy of generation supply?
How is reserve sharing to meet state or
regional generation adequacy standards
accomplished in competitive markets?
How can other institutions/market
processes provide an effective substitute
for reserve sharing?
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D. Transmission Investment and
Regulation
1. What are the most important factors
that affect whether transmission will be
built? What are ways to improve the
process? What difficulties have
transmission owners had in upgrading
or building new transmission facilities?
What are the prospects for merchant
transmission?
2. Over the past 10 years, what have
been the trends in investments in
transmission by utilities by state or
region? Are there any prevailing
patterns in transmission investments in
upgrades and replacement of existing
plant versus new lines,
interconnections, automation? Have
these patterns of investment shifted over
this period? Are there any projected
changes in patterns of transmission
investment over the next 5 years?
3. How are transmission needs of
merchant generators and renewable
energy projects included in regional or
utility transmission planning and
upgrades?
4. How has the establishment of
Regional Transmission Organizations
(RTOs) changed transmission
operations, transmission planning, and
investment patterns?
5. Within a region or RTO, is there a
different process for transmission
upgrades that are not required for
reliability but would increase access to
lower priced power in areas with
economic congestion?
6. In the absence of RTOs, how is
transmission planning, siting, and
construction for regional needs
coordinated among utilities, generators,
and State regulators? What challenges
do transmission owners face upgrading
or building new transmission facilities?
7. How have transmission costs
changed for transmission owners and
for transmission customers over the past
10 years? What are the reasons for any
increases or decreases?
E. Wholesale Market Transparency and
Information
1. Do purchasers and sellers view
markets as providing stable, transparent
prices? Are there differences among
products and markets?
2. Is there sufficient timely and
accurate publicly available information
to assure that market participants can
adequately assess the economics of
proposed wholesale power transactions
or assess the financial implications of
self build versus competitive
alternatives for generation supply?
3. How can any information deficits
be remedied to improve the utility of
market information? Are there any
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competitive risks associated with greater
transparency of prices or of other
information about market participants?
4. Are there open and transparent
processes by which load serving entities
solicit proposals for generation from
independent firms and/or from affiliated
generators?
Retail Market Questions
Commentors can answer the following
questions based on their knowledge and
experience in any state with retail
competition:
A. Retail Markets Overview
1. What factors or measures should
the Task Force examine in reviewing
state retail choice experiences? How
should these factors and measures be
evaluated?
2. How should the Task Force assess
the performance of evolving competitive
retail markets?
3. How can the performance of
competitive retail markets for retail
customers be measured in the absence
of competitive suppliers for residential
and small business customers in many
areas?
4. Why did your state implement a
retail electric choice program?
5. Why did your state decide not to
implement a retail electric choice
program?
B. State Retail Choice Experience
1. How have consumers benefited
from retail electric competition? How
have consumers been harmed by retail
electric competition?
2. How have retail customer prices
changed since the beginning of the
transition to retail choice? Have the
changes been comparable across all
classes of customers?
3. How many alternative competitive
retail suppliers are currently soliciting
or accepting new customers in each
service area? Has the number increased
or decreased since the state introduced
retail choice?
4. Does the availability of alternative
competitive suppliers differ among
service areas, customer classes, load
size, rural and urban areas, or other
geographic areas, or by credit policies?
If so, why? If not, why not?
5. Have suppliers offered new types of
products and services (e.g., time of day
pricing, interruptible contracts, green
power, etc.) in states where retail
competition has been implemented? If
so, describe the products and what
customer response has been.
6. How do retail customers obtain
information about competitive
alternatives? Do retail consumers have
enough information to readily make
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60821
informed choices among competing
suppliers?
7. Does the state allow groups of retail
customers to aggregate their electricity
demand? How are they structured?
What customer groups are included? Is
participation on an opt-in or an opt-out
basis? Has aggregation enabled
consumers to benefit from retail
electricity competition? If not, why not?
8. Now that many state-mandated
transition periods to phase-in retail
competition are ending, what issues do
states face to ensure competitive retail
markets?
C. Retail Supply Questions in States
With Retail Competition
1. How does the state program address
assurance of adequate generation
supplies for default service customers
(i.e., customers that: (a) Do not choose
a competitive provider, or (b) have lost
their competitive supplier for whatever
reason)?
2. How do default service obligations
affect retail power competition? Do the
transmission services allowed for
default service obligations affect retail
competition and, if so, how? What
changes, if any, would you suggest in
these transmission services?
3. How has the development of RTOs
affected the development of retail
competition in the state?
4. Did the state require that the
incumbent utility divest all or some of
its generation assets used to serve its
retail native load when retail
competition was introduced? Did
incumbent utilities voluntarily divest
generation assets as part of restructuring
to implement retail competition? Did
incumbent utilities transfer ownership
of generation assets used to serve native
load to an affiliated entity?
5. What has been the result of
generation ownership transfers serving
the state or region since the start of
retail competition? Has there been a
consolidation of generation ownership
in the state or region?
6. If a retail load serving utility no
longer owns sufficient generation assets
to meet its obligations to its retail
customers (existing customers, or as the
supplier of last resort or default service
provider) what mechanism (e.g., spot
market purchases, buy back or output
contracts, etc.) does it use to obtain
generation services to fulfill these
obligations? What share of a utility’s
load is obtained via the different
mechanisms? How are these shares
trending?
7. How do non-utility retail service
providers in the state secure access to
transmission and distribution services
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Federal Register / Vol. 70, No. 201 / Wednesday, October 19, 2005 / Notices
needed to deliver power to their retail
customers?
8. What difficulties have retail
supplier entrants encountered in
entering the market? What conditions/
incentives attract suppliers to retail
markets?
D. Demand Side Participation
1. How do rate structures affect the
incentives of large, medium, or small
electric customers to participate in
demand side response programs? Does
this effect differ if a state has a retail
choice program?
2. What measures have states taken to
make customer demand responsive to
changes in availability and price of
electricity supply? Do these measures
differ if a state has a retail choice
program?
3. What mechanisms allow for the
participation of load response measures
‘‘ interruptible load, self-generation,
demand-side management, conservation
and energy efficiency measures as
alternatives in wholesale electric
markets and or load serving utility
resource portfolios? How has the
performance of these measures been
monitored?
4. Have states adopted alternatives to
average cost pricing to encourage
demand response?
5. What has been the effect on
demand and demand elasticity in light
of these measures?
6. How prevalent is the use of
distributed resources (e.g., distributed
generation and distributed energy
storage) within the state?
7. To what extent are retail customers
within the state or region increasing use
of distributed resources and what types
of resources are involved?
E. Rising Fuel Prices
1. Are changes in prices for oil,
natural gas, and coal affecting the
results of competitive wholesale
markets and viability of competitive
suppliers and if so, how?
2. How are changes in prices for oil,
natural gas, and coal affecting retail
electricity costs?
3. Are there differences in retail price
impacts between states and/or utility
systems operating under retail
competition models and those that
operate under traditional utility cost
based rate models?
How To File Comments
Any interested person may submit a
written comment that will be
considered part of the public record.
Comments may be filed electronically
via the e-Filing link on the Federal
Energy Regulatory Commission’s Web
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site at https://www.ferc.gov for Docket
No. AD05–17–000. Most standard word
processing formats are accepted, and the
e-Filing link provides instructions for
how to Login and complete an
electronic filing. First-time users will
have to establish a user name and
password. User assistance for electronic
filing is available at 202–208–0258 or by
e-mail to efiling at ferc.gov. Comments
should not be submitted to the e-mail
address. Commentors filing
electronically do not need to make a
paper filing. Commentors that are not
able to file comments electronically
must send an original of their comments
to: Federal Energy Regulatory
Commission, Office of the Secretary,
888 First Street NE., Washington, DC
20426.
This filing is accessible on-line at
https://www.ferc.gov, using the
‘‘eLibrary’’ link and is available for
review in the Commission’s Public
Reference Room in Washington, DC. For
assistance with any FERC Online
service, please e-mail
FERCOnlineSupport@ferc.gov, or call
(866) 208–3676 (toll free). For TTY, call
(202) 502–8659.
Comment Date: 5 p.m. eastern time on
November 18, 2005.
Magalie R. Salas,
Secretary.
[FR Doc. 05–20896 Filed 10–18–05; 8:45 am]
BILLING CODE 5717–01–P
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[OPP–2005–0257; FRL–7741–3]
Cambridge Environmental Inc. and
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]]>Agencies
[Federal Register Volume 70, Number 201 (Wednesday, October 19, 2005)]
[Notices]
[Pages 60819-60822]
From the Federal Register Online via the Government Printing Office [www.gpo.gov]
[FR Doc No: 05-20896]
-----------------------------------------------------------------------
DEPARTMENT OF ENERGY
Federal Energy Regulatory Commission
[Docket No. AD05-17-000]
Electric Energy Market Competition Task Force; Notice Requesting
Comments on Wholesale and Retail Electricity Competition
October 13, 2005.
Overview
Section 1815 of the Energy Policy Act of 2005 requires the Electric
Energy Market Competition Task Force to conduct a study of competition
in wholesale and retail markets for electric energy in the United
States. Over the past several years, wholesale competition has
developed unevenly in many regions of the country. Moreover, fewer than
20 States have adopted retail choice programs that allow some
electricity consumers to choose their retail electric generation
supplier. The purpose of this study is to analyze and report to
Congress on the critical elements for effective wholesale and retail
competition, the status of each element, impediments to realizing each
element, and suggestions for overcoming these impediments.
In recent years, some states and the Federal government have taken
steps to encourage competition in the electric power industry. In the
Energy Policy Act of 2005, Congress established an inter-agency task
force, known as the ``Electric Energy Market Competition Task Force''
(the Task Force), to conduct a study and analysis of competition within
the wholesale markets and retail markets for electric energy in the
United States. The Task Force consists of 5 members:
(1) 1 employee of the Department of Justice, appointed by the
Attorney General of the United States--J. Bruce McDonald, Deputy
Assistant Attorney General, Antitrust Division; (202) 514-1157,
bruce.mcdonald@usdoj.gov.
(2) 1 employee of the Federal Energy Regulatory Commission,
appointed by the Chairperson of that Commission--Michael Bardee,
Associate General Counsel, Office of the General Counsel-Markets,
Tariffs, and Rates; (202) 502-8068, michael.bardee@ferc.gov.
(3) 1 employee of the Federal Trade Commission, appointed by the
Chairperson of that Commission--Michael Wroblewski, Assistant General
Counsel for Policy Studies; (202) 326-2166, mwroblewski@ftc.gov.
(4) 1 employee of the Department of Energy, appointed by the
Secretary of Energy--David Meyer, Deputy Director, Division of
Permitting, Siting, and Analysis, Office of Electricity Delivery and
Energy Reliability; (202) 586-1411, David.Meyer@hq.doe.gov.
(5) 1 employee of the Rural Utilities Service, appointed by the
Secretary of Agriculture--Karen Larsen, Office of Assistant
Administrator, Electric Programs (202) 720-9545, Karen.Larsen@usda.gov.
Section 1815(c) of the Energy Policy Act of 2005 requires the Task
Force to ``consult with and solicit comments from any advisory entity
of the task force, the States, representatives of the electric power
industry, and the public.'' This Notice begins this process. The Task
Force also will publish a draft final report for public comment, before
submitting the final version to Congress as required by Section
1815(b)(2)(B).
Listed below is a series of questions for which the Task Force
seeks public comment. For both wholesale and retail competition for
electric power, we focus on the current state of competition and on
factors that help support competition, or that otherwise may limit
competition, among suppliers and buyers in regional wholesale markets
and retail markets at the state level. The questions listed below are
by no means exhaustive. The Task Force encourages commentors to raise
any other additional factors that affect competition in wholesale and
retail electric power markets. It is not necessary to respond to each
question. Rather, it would be helpful for
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respondents to provide, for example, specific information about market
responses to particular governing regulations, or to compare and
contrast the market reaction to the means individual states have used
to address various retail competition issues (e.g., generation siting,
provider of last resort pricing, etc.).
Overview Questions
1. What are the critical elements or attributes of competition in
wholesale electricity markets that the Task Force should examine?
2. What are the critical elements or attributes of competition in
retail electricity markets that the Task Force should examine?
3. What benefits have occurred because of competition in wholesale
and retail electricity markets? What additional benefits are expected?
What benefits were forecasted and have not occurred? Why? What harms
have occurred because of competition in wholesale and retail
electricity markets?
4. What are the major public policy concerns that the Task Force
should examine in its review of competition in wholesale and retail
electricity markets?
5. In what significant ways do wholesale and retail electricity
markets differ from other energy or commodity markets? What
implications do their differences have for public policy?
Wholesale Market Questions
Commentors should answer with a specific regional wholesale market
in mind and should be as specific as possible.
A. Wholesale Supply Trading and Participation
1. To what extent does wholesale trading help result in an economic
and reliable supply of electricity in each region? What are ways to
improve the provision of an economic and reliable supply of
electricity?
2. What share of electric power used to serve retail (or ultimate
consumer) load is obtained through wholesale market transactions in
each state or region? In what ways has this share changed over the past
10 years and the past 5 years and why?
3. What share of electric power used to serve ultimate consumer
load is generated by a utility for its own native load? What share of
electric power used to serve utility customer load comes from utility
affiliates? What share comes from unaffiliated generators?
4. What opportunities exist for generation owners to sell output in
wholesale markets?
5. What opportunities exist for wholesale power buyers to purchase
electricity in wholesale markets? Is demand (negawatts) a product that
can be traded in the wholesale market?
6. Is there an organized regional market or exchange serving buyers
and sellers in the region? What products does the organized market
provide? What percentage of energy supplied is secured through
organized markets and through bilateral trades? Are there liquid
trading points in the region? What are the volumes traded? What is the
trend of bid/ask spreads (getting greater or smaller)?
7. To what extent do wholesale buyers and sellers participate in
futures or others commodity markets or transactions to balance the
financial risks of competitive electricity markets? How liquid are
forward markets in different regions and how far ahead can one transact
in these markets?
8. What role have credit issues played in the ability of market
participants to participate in wholesale markets, including forward
markets?
9. Are there competitive processes by which distribution utilities
solicit proposals for native load or default service?
10. How can changes and trends in wholesale market prices by region
be measured?
11. How should the performance of wholesale markets in serving the
needs of various types of power sellers (e.g., marketer, generator,
independent producer, merchant, public utility, nonpublic utility,
qualified facility, renewable power producer, co-generator) be
measured?
12. How has restructuring of incumbent utility operations and the
introduction of competitive retail markets in retail choice states
affected participation in regional wholesale markets? Has the
introduction of retail markets affected the level of long-term
contracting in wholesale markets?
13. Please describe instances in which competition has resulted in
relatively higher prices or lower reliability in a specific regional
market.
B. Generation Ownership
1. How has ownership of electric generating plants changed over the
past 10 years?
2. In the past 10 years, when generations assets have been sold or
transferred, how much capacity was sold or transferred to (a) Utility
or utility affiliates, (b) existing non-utility market participants;
(c) new market participants?
3. How much existing merchant or non-utility generation assets have
been sold or transferred? What were the reasons for these transactions?
4. How much existing capacity has been sold or transferred to
utilities and converted to rate-based assets? Of those how many were
previously affiliated with a utility and how many were purchased from
other entities?
C. Generation Adequacy
1. How is generation adequacy addressed in each region or system?
Is there a specific enforceable requirement that load serving entities
or market participants must meet? How is planning for generation
adequacy conducted?
2. Has new generation construction kept pace with demand growth in
the state or market region? If not, why not? What are the most
important factors that affect whether generation will be built?
3. What role does the ability to enter into long-term contracts
play in financing new generation projects?
4. What generation facilities have been installed in the past five
years? What was the experience in the process?
5. What generation facilities have been cancelled in the past five
years and why?
6. What difficulties, if any, have developers of new generation
facilities encountered in bringing generation supply to market? (E.g.,
difficulties in financing, siting, permitting, licensing,
interconnection, transmission access, fuel supply.) What are ways to
improve the process?
7. Are there instances in the past five years in which a new
generation facility has been completed that caused prices in a
previously congested area to decline?
8. How do the approaches and responsibilities for assuring the
availability of sufficient generation capacity to meet peak load and
load growth vary among regions and states that have retail choice and/
or tightly organized regional markets and those that do not?
9. What incentives do competitive suppliers have to maintain
adequate reserve capacity?
10. What incentives or responsibilities do load serving utilities
have to maintain adequate reserve capacity?
11. How can competitive markets assure adequacy of generation
supply? How is reserve sharing to meet state or regional generation
adequacy standards accomplished in competitive markets? How can other
institutions/market processes provide an effective substitute for
reserve sharing?
[[Page 60821]]
D. Transmission Investment and Regulation
1. What are the most important factors that affect whether
transmission will be built? What are ways to improve the process? What
difficulties have transmission owners had in upgrading or building new
transmission facilities? What are the prospects for merchant
transmission?
2. Over the past 10 years, what have been the trends in investments
in transmission by utilities by state or region? Are there any
prevailing patterns in transmission investments in upgrades and
replacement of existing plant versus new lines, interconnections,
automation? Have these patterns of investment shifted over this period?
Are there any projected changes in patterns of transmission investment
over the next 5 years?
3. How are transmission needs of merchant generators and renewable
energy projects included in regional or utility transmission planning
and upgrades?
4. How has the establishment of Regional Transmission Organizations
(RTOs) changed transmission operations, transmission planning, and
investment patterns?
5. Within a region or RTO, is there a different process for
transmission upgrades that are not required for reliability but would
increase access to lower priced power in areas with economic
congestion?
6. In the absence of RTOs, how is transmission planning, siting,
and construction for regional needs coordinated among utilities,
generators, and State regulators? What challenges do transmission
owners face upgrading or building new transmission facilities?
7. How have transmission costs changed for transmission owners and
for transmission customers over the past 10 years? What are the reasons
for any increases or decreases?
E. Wholesale Market Transparency and Information
1. Do purchasers and sellers view markets as providing stable,
transparent prices? Are there differences among products and markets?
2. Is there sufficient timely and accurate publicly available
information to assure that market participants can adequately assess
the economics of proposed wholesale power transactions or assess the
financial implications of self build versus competitive alternatives
for generation supply?
3. How can any information deficits be remedied to improve the
utility of market information? Are there any competitive risks
associated with greater transparency of prices or of other information
about market participants?
4. Are there open and transparent processes by which load serving
entities solicit proposals for generation from independent firms and/or
from affiliated generators?
Retail Market Questions
Commentors can answer the following questions based on their
knowledge and experience in any state with retail competition:
A. Retail Markets Overview
1. What factors or measures should the Task Force examine in
reviewing state retail choice experiences? How should these factors and
measures be evaluated?
2. How should the Task Force assess the performance of evolving
competitive retail markets?
3. How can the performance of competitive retail markets for retail
customers be measured in the absence of competitive suppliers for
residential and small business customers in many areas?
4. Why did your state implement a retail electric choice program?
5. Why did your state decide not to implement a retail electric
choice program?
B. State Retail Choice Experience
1. How have consumers benefited from retail electric competition?
How have consumers been harmed by retail electric competition?
2. How have retail customer prices changed since the beginning of
the transition to retail choice? Have the changes been comparable
across all classes of customers?
3. How many alternative competitive retail suppliers are currently
soliciting or accepting new customers in each service area? Has the
number increased or decreased since the state introduced retail choice?
4. Does the availability of alternative competitive suppliers
differ among service areas, customer classes, load size, rural and
urban areas, or other geographic areas, or by credit policies? If so,
why? If not, why not?
5. Have suppliers offered new types of products and services (e.g.,
time of day pricing, interruptible contracts, green power, etc.) in
states where retail competition has been implemented? If so, describe
the products and what customer response has been.
6. How do retail customers obtain information about competitive
alternatives? Do retail consumers have enough information to readily
make informed choices among competing suppliers?
7. Does the state allow groups of retail customers to aggregate
their electricity demand? How are they structured? What customer groups
are included? Is participation on an opt-in or an opt-out basis? Has
aggregation enabled consumers to benefit from retail electricity
competition? If not, why not?
8. Now that many state-mandated transition periods to phase-in
retail competition are ending, what issues do states face to ensure
competitive retail markets?
C. Retail Supply Questions in States With Retail Competition
1. How does the state program address assurance of adequate
generation supplies for default service customers (i.e., customers
that: (a) Do not choose a competitive provider, or (b) have lost their
competitive supplier for whatever reason)?
2. How do default service obligations affect retail power
competition? Do the transmission services allowed for default service
obligations affect retail competition and, if so, how? What changes, if
any, would you suggest in these transmission services?
3. How has the development of RTOs affected the development of
retail competition in the state?
4. Did the state require that the incumbent utility divest all or
some of its generation assets used to serve its retail native load when
retail competition was introduced? Did incumbent utilities voluntarily
divest generation assets as part of restructuring to implement retail
competition? Did incumbent utilities transfer ownership of generation
assets used to serve native load to an affiliated entity?
5. What has been the result of generation ownership transfers
serving the state or region since the start of retail competition? Has
there been a consolidation of generation ownership in the state or
region?
6. If a retail load serving utility no longer owns sufficient
generation assets to meet its obligations to its retail customers
(existing customers, or as the supplier of last resort or default
service provider) what mechanism (e.g., spot market purchases, buy back
or output contracts, etc.) does it use to obtain generation services to
fulfill these obligations? What share of a utility's load is obtained
via the different mechanisms? How are these shares trending?
7. How do non-utility retail service providers in the state secure
access to transmission and distribution services
[[Page 60822]]
needed to deliver power to their retail customers?
8. What difficulties have retail supplier entrants encountered in
entering the market? What conditions/incentives attract suppliers to
retail markets?
D. Demand Side Participation
1. How do rate structures affect the incentives of large, medium,
or small electric customers to participate in demand side response
programs? Does this effect differ if a state has a retail choice
program?
2. What measures have states taken to make customer demand
responsive to changes in availability and price of electricity supply?
Do these measures differ if a state has a retail choice program?
3. What mechanisms allow for the participation of load response
measures `` interruptible load, self-generation, demand-side
management, conservation and energy efficiency measures as alternatives
in wholesale electric markets and or load serving utility resource
portfolios? How has the performance of these measures been monitored?
4. Have states adopted alternatives to average cost pricing to
encourage demand response?
5. What has been the effect on demand and demand elasticity in
light of these measures?
6. How prevalent is the use of distributed resources (e.g.,
distributed generation and distributed energy storage) within the
state?
7. To what extent are retail customers within the state or region
increasing use of distributed resources and what types of resources are
involved?
E. Rising Fuel Prices
1. Are changes in prices for oil, natural gas, and coal affecting
the results of competitive wholesale markets and viability of
competitive suppliers and if so, how?
2. How are changes in prices for oil, natural gas, and coal
affecting retail electricity costs?
3. Are there differences in retail price impacts between states
and/or utility systems operating under retail competition models and
those that operate under traditional utility cost based rate models?
How To File Comments
Any interested person may submit a written comment that will be
considered part of the public record. Comments may be filed
electronically via the e-Filing link on the Federal Energy Regulatory
Commission's Web site at https://www.ferc.gov for Docket No. AD05-17-
000. Most standard word processing formats are accepted, and the e-
Filing link provides instructions for how to Login and complete an
electronic filing. First-time users will have to establish a user name
and password. User assistance for electronic filing is available at
202-208-0258 or by e-mail to efiling at ferc.gov. Comments should not
be submitted to the e-mail address. Commentors filing electronically do
not need to make a paper filing. Commentors that are not able to file
comments electronically must send an original of their comments to:
Federal Energy Regulatory Commission, Office of the Secretary, 888
First Street NE., Washington, DC 20426.
This filing is accessible on-line at https://www.ferc.gov, using the
``eLibrary'' link and is available for review in the Commission's
Public Reference Room in Washington, DC. For assistance with any FERC
Online service, please e-mail FERCOnlineSupport@ferc.gov, or call (866)
208-3676 (toll free). For TTY, call (202) 502-8659.
Comment Date: 5 p.m. eastern time on November 18, 2005.
Magalie R. Salas,
Secretary.
[FR Doc. 05-20896 Filed 10-18-05; 8:45 am]
BILLING CODE 5717-01-P
