Energy Policy Act of 2005, P.L. 109-58: Electricity Provisions

CRS Report for Congress
Energy Policy Act of 2005, P.L. 109-58:
Electricity Provisions
January 24, 2006
Amy Abel
Specialist in Energy Policy
Resources, Science, and Industry Division


Congressional Research Service ˜ The Library of Congress

Energy Policy Act of 2005, P.L. 109-58:
Electricity Provisions
Summary
The Energy Policy Act of 2005 (P.L. 109-58), signed by President Bush on
August 8, 2005, was the first omnibus energy legislation enacted in more than a
decade. Major provisions include tax incentives for domestic energy production and
energy efficiency, a mandate to double the nation’s use of biofuels, faster procedures
for energy production on federal lands, and authorization of numerous federal energy
research and development programs. This report describes the electricity provisions.
It will not be updated.
Title XII authorizes the Federal Energy Regulatory Commission (FERC) to
certify a national electric reliability organization (ERO) to enforce mandatory
reliability standards for the bulk power system. All ERO standards must be approved
by FERC. The ERO can impose penalties on a user, owner, or operator of the bulk
power system for violations of any FERC-approved reliability standard.
The Secretary of Energy is required to conduct a study of electric transmission
congestion every three years and may designate a geographic area as being congested.
Under certain conditions, FERC is authorized to issue construction permits in
congested areas. Permit holders may petition in U.S. District Court to acquire rights-
of-way through eminent domain. An applicant for federal authorization to site
transmission facilities on federal lands could request that the Department of Energy
be the lead agency to coordinate environmental review and other federal
authorization. If a federal agency has denied an authorization required by a
transmission or distribution facility, the denial could be appealed by the applicant or
relevant state to the President.
Section 210 of the Public Utility Regulatory Policies Act (PURPA) had required
utilities to purchase power from all qualifying facilities and small power producers
at a rate based on the utilities’ avoided cost. The Energy Policy Act repeals the
PURPA mandatory purchase requirement for new contracts if FERC finds that a
competitive electricity market exists and a qualifying facility has adequate access to
wholesale markets.
Also repealed is the Public Utility Holding Company Act of 1935 (PUHCA),
which restricted the structure of holding companies of investor-owned utilities and
provided for Securities and Exchange Commission (SEC) regulation of mergers and
diversification proposals. FERC and state regulatory bodies must be given access to
utility books and records.
FERC is directed to facilitate price transparency in wholesale electric markets,
relying on existing price publishers and providers of trade processing services to the
maximum extent possible. However, FERC may establish an electronic information
system if it determines that existing price information is not adequate. FERC is
given approval authority over the acquisition of securities and the merger, sale, lease,
or disposition of facilities under FERC’s jurisdiction with a value in excess of $10
million.



Contents
In troduction ......................................................1
Title XII — Electricity..............................................1
Sec. 1201................................................1
Subtitle A — Reliability Standards................................1
Summary of Provisions.....................................1
Subtitle B — Transmission Infrastructure Modernization...............2
Siting of Interstate Electric Transmission Facilities (Sec. 1221)......2
Third-Party Finance (Sec. 1222)..............................3
Advanced Transmission Technologies (Sec. 1223)................3
Advanced Power System Technology Incentive Program
(Sec. 1224)...........................................3
Subtitle C — Transmission Operation Improvements..................4
Open Nondiscriminatory Access (Sec. 1231)....................4
Federal Utility Participation in Regional Transmission Organizations
(Sec. 1232)..........................................4
Native Load Service Obligation (Sec. 1233).....................4
Study on the Benefits of Economic Dispatch (Sec. 1234)...........5
Protection of Transmission Contracts in the Pacific Northwest
(Sec. 1235)...........................................5
Sense of Congress Regarding Locational Installed Capacity
Mechanism (Sec. 1236).................................5
Subtitle D — Transmission Rate Reform...........................5
Transmission Infrastructure Investment (Sec. 1241)...............5
Funding New Interconnection and Transmission Upgrades
(Sec. 1242)...........................................5
Subtitle E — Amendments to the Public Utility Regulatory
Policies Act (PURPA)......................................6
Net Metering and Additional Standards (Sec. 1251)...............6
Smart Metering (Sec. 1252)..................................6
Cogeneration and Small Power Production Purchase
and Sale Requirements (Sec. 1253)........................6
Interconnection (Sec. 1254)..................................8
Subtitle F — Repeal of the Public Utility Holding Company Act
of 1935 (PUHCA).........................................8
Short Title (Sec. 1261)......................................8
Definitions (Sec. 1262).....................................8
Repeal of the Public Utility Holding Company Act of 1935
(Sec. 1263)...........................................9
Federal Access to Books and Records (Sec. 1264)...............11
State Access to Books and Records (Sec. 1265).................11
Exemption Authority (Sec. 1266)............................11
Affiliate Transactions (Sec. 1267)............................11
Applicability (Sec. 1268)...................................12
Effect on Other Regulations (Sec. 1269).......................12
Enforcement (Sec. 1270)...................................12
Savings Provisions (Sec. 1271)..............................12



Transfer of Resources (Sec. 1273)............................12
Effective Date (Sec. 1274)..................................12
Service Allocation (Sec. 1275)..............................12
Authorization of Appropriations (Sec. 1276)...................13
Conforming Amendments to the Federal Power Act (Sec. 1277)....13
Subtitle G — Market Transparency, Enforcement, and
Consumer Protection......................................13
Electricity Market Transparency (Sec. 1281)...................13
False Statements (Sec. 1282)................................13
Market Manipulation (Sec. 1283)............................14
Enforcement (Sec. 1284)...................................14
Refund Effective Date (Sec. 1285)...........................14
Refund Authority (Sec. 1286)...............................14
Consumer Privacy and Unfair Trade Practices (Sec. 1287).........14
Authority of Court to Prohibit Individuals from Serving
As Officers, Directors, and Energy Traders (Sec. 1288).......14
Merger Review Reform (Sec. 1289)..........................15
Relief for Extraordinary Violations (Sec. 1290).................15
Subtitle H — Definitions.......................................15
Definitions (Sec. 1291)....................................15
Subtitle I — Technical and Conforming Amendments................15
Conforming Amendments (Sec. 1295)........................15
Subtitle J — Economic Dispatch.................................16
Economic Dispatch (Sec. 1298)..............................16
Title XVIII — Studies.............................................16
Effect of Electrical Contaminants Unreliability of Energy
Production Systems (Sec. 1822).........................16
Final Action on Refunds for Excessive Charges (Sec. 1824).......16
Study the Benefits of Economic Dispatch (Sec. 1832)............16
Transmission System Monitoring (Sec. 1839)...................16



Energy Policy Act of 2005, P.L. 109-58:
Electricity Provisions
Introduction
The Energy Policy Act of 2005 (P.L. 109-58), signed by President Bush on
August 8, 2005, was the first omnibus energy legislation enacted in more than a
decade. Major provisions include tax incentives for domestic energy production and
energy efficiency, a mandate to double the nation’s use of biofuels, faster procedures
for energy production on federal lands, and authorization of numerous federal energy
research and development programs. This report describes the electricity provisions.
Title XII — Electricity
Sec. 1201. Short title. This title may be cited as the “Electric Reliability Act
of 2005.”
Subtitle A — Reliability Standards
Summary of Provisions. This subtitle is intended to provide federal
jurisdiction over activities that are required to support reliability of the U.S. bulk
power system. Clarifying the Federal Energy Regulatory Commission’s (FERC)
authority to establish and regulate an electric reliability organization (ERO) is
intended to improve reliability as restructuring of the U.S. bulk power system
proceeds.
Electric Reliability Standards (Sec. 1211). This section requires FERC
to promulgate rules within 180 days of enactment to create a FERC-certified ERO.
The North American Electric Reliability Council (NERC) currently has responsibility
for reliability of the bulk power system. NERC has established reliability guidelines
but has no enforcement authority. Before enactment of P.L. 109-58, the Federal1
Power Act gave FERC jurisdiction over unbundled transmission and authority to
regulate wholesale rates; however, no authority was provided to regulate reliability.
Under this section, the ERO will develop and enforce reliability standards for the
bulk power system, including cybersecurity protection. All ERO standards will be
approved by FERC. Under this title, the ERO can impose penalties on a user, owner,
or operator of a bulk power system that violates any FERC-approved reliability
standard. In addition, FERC can order compliance with a reliability standard and can
impose a penalty if FERC finds that a user, owner, or operator of a bulk power


1 16 U.S.C. 791a et seq.

system has engaged in or is about to engage in a violation of a reliability standard.
This provision does not give an ERO or FERC authorization to order construction of
additional generation or transmission capacity.
This provision also requires that FERC establish a regional advisory body if
requested by at least two-thirds of the states within a region that have more than half
of their electric load served within that region. The advisory body will be composed
of one member from each participating state in the region, appointed by the governor
of each state, and is able to provide advice to the ERO or FERC on reliability
standards, proposed regional entities, proposed fees, and any other responsibilities
requested by FERC. The entire reliability provision does not apply to Alaska or
Hawaii. The state of New York is authorized to develop rules that would result in
greater reliability for New York, as long as those rules do not result in lower
reliability for neighboring states.
If the penalties employed by the ERO are not successful, then FERC has the
authority to enforce penalties for entities that do not comply with reliability
standards. Establishing this new relationship between FERC and the ERO could
have the potential to improve coordination between market functions and reliability
functions.
Subtitle B — Transmission Infrastructure Modernization
Siting of Interstate Electric Transmission Facilities (Sec. 1221). The
Secretary of Energy is required to conduct a study of electric transmission congestion
every three years. Based on the findings, the Secretary of Energy may designate a
geographic area as being congested. Under certain conditions, FERC is authorized
to issue construction permits. Under new Section 216(d) of the Federal Power Act
(FPA), affected states, federal agencies, Indian tribes, property owners, and other
interested parties will have an opportunity to present their views and
recommendations with respect to the need for, and impact of, a proposed construction
permit. However, there is no requirement for a specific comment period. New FPA
Section 216(e) will allow permit holders to petition in U.S. District Court to acquire
rights-of-way through the exercise of the right of eminent domain. Any exercise of
eminent domain authority would be considered to be takings of private property for
which just compensation is due. New FPA Section 216(g) does not state whether
property owners would be required to reimburse compensation if the rights-of-way
were transferred back to the owner.
An applicant for federal authorization to site transmission facilities on federal
lands could request that the Department of Energy be the lead agency to coordinate
environmental review and other federal authorization. Once a completed application
is submitted, all related environmental reviews are required to be completed within
one year unless another federal law makes that impossible. FPA Section 216(h)
gives the Department of Energy (DOE) new authority to prepare environmental
documents and appears to give DOE additional decision-making authority for rights-
of-way and siting on federal lands. This would appear to give DOE input into the
decision process for creating rights-of-way. Review under Section 503 of the Federal



Land Policy and Management Act2 could be streamlined by relying on prior analyses.
If a federal agency has denied an authorization required by a transmission or
distribution facility, the denial could be appealed by the applicant or relevant state to
the President. The President is required to issue a decision within 90 days of the
appeal’s filing. With congressional approval, states may enter into interstate
compacts for the purposes of siting transmission facilities and the Secretary of
Energy could provide technical assistance. This section does not apply to the Electric
Reliability Council of Texas (ERCOT).
Third-Party Finance (Sec. 1222). The Western Area Power Administration
(WAPA) and the Southwestern Power Administration (SWPA) are able either to
continue to design, develop, construct, operate, maintain, or own transmission
facilities within their regions or to participate with other entities for the same
purposes if the Secretary of Energy designates the area as a National Interest Electric
Transmission Corridor and if the facility will reduce congestion or is needed to
accommodate projected increases in demand for transmission capacity. The project
is required to be consistent with the needs identified by the appropriate Regional
Transmission Organization or Independent System Operator. Under certain
circumstances, the Secretary of Energy, acting through WAPA and/or SWPA, may
design, develop, construct, operate, maintain, or own an electric power transmission
facility in the WAPA and SWPA region. No more than $100 million from third-
party financing may be used during fiscal years 2006 through 2015. Before
enactment, the enabling statutes for power marketing administrations could have
restricted third-party financing, construction, operation, and maintenance of3
transmission facilities.
Advanced Transmission Technologies (Sec. 1223). FERC is directed
to encourage deployment of advanced transmission technologies.
Advanced Power System Technology Incentive Program (Sec.
1224). A program is established to provide incentive payments to owners or
operators of advanced power generation systems. Subject to the availability of funds,
1.8 cents per kilowatt-hour will be paid to the owner or operator of a qualifying
advanced power system technology facility. For facilities that the Secretary of
Homeland Security and the Secretary of Energy determine are “qualifying security
and assured power facilities,” an additional 0.7 cents per kilowatt-hour will be paid
to the owner or operator of such a facility. Under the incentive program, the first
10,000,000 kilowatt-hours produced in any facility in a fiscal year are eligible for the
incentives. Eligible systems include advanced fuel cells, turbines, or hybrid power
systems. For FY2006 through FY2012, an annual appropriation of $10 million is
authorized.


2 43 U.S.C. 1763.
3 16 U.S.C. 460 (SWPA) and 43 U.S.C. 485 (WAPA).

Subtitle C — Transmission Operation Improvements
Open Nondiscriminatory Access (Sec. 1231). FERC is authorized to
require, by rule or order, unregulated transmitting utilities (power marketing
administrations, state entities, and rural electric cooperatives) to charge rates
comparable to what they charge themselves and require that the terms and conditions
of the sales be comparable to those required of other utilities. Before enactment of
P.L. 109-58, under the Federal Power Act (Section 201(f)), federal power marketing
administrations, state entities, and rural electric cooperatives were not subject to
FERC’s rate-making. Under this provision, exemptions are established for utilities
selling less than 4 million megawatt-hours of electricity per year, for distribution
utilities, and for utilities that own or operate transmission facilities that are not
necessary to facilitate a nationwide interconnected transmission system. This
exemption can be revoked to maintain transmission system reliability. FERC is not
authorized to order states or municipalities to take action under this section if such
action would constitute a private use under Section 141 of the Internal Revenue Code
of 1986. FERC may remand transmission rates to an unregulated transmitting utility
if the rates do not comply with this section. FERC is not authorized to order an
unregulated transmitting utility to join a Regional Transmission Organization or other
FERC-approved independent transmission organization. (This section is often
referred to as “FERC-lite.”)
Federal Utility Participation in Regional Transmission
Organizations (Sec. 1232). Federal utilities (power marketing administrations
or the Tennessee Valley Authority) are authorized to participate in regional
transmission organizations. A law allowing federal utilities to study formation and
operation of a regional transmission organization is repealed (16 U.S.C. 824n).
Native Load Service Obligation (Sec. 1233). This section amends the
Federal Power Act to clarify that a load-serving entity is entitled to use its
transmission facilities or firm transmission rights to serve its existing customers
before it is obligated to make its transmission capacity available for other uses.
FERC is not able to change any approved allocation of transmission rights by an
Regional Transmission Organization (RTO) or Independent System Operator (ISO)
approved prior to January 1, 2005. A government entity that owns transmission
facilities used predominantly to support its own water pumping facilities is provided
protections for transmission service to such facilities comparable to protections
provided to load-serving entities. This section does not apply to ERCOT and does
apply to load-serving entities located within the service area of the Tennessee Valley
Authority. Within one year of enactment, FERC is required to issue a rule or order
on long-term transmission rights and organized markets.
Section 201 of the Federal Power Act gives FERC jurisdiction over “the
transmission of electric energy in interstate commerce and the sale of such energy at
wholesale in interstate commerce.” Section 205 of the Federal Power Act prohibits
utilities from granting “undue preference or advantage to any person or subject any
person to any undue prejudice or disadvantage” (16 U.S.C. 824). The new language
of this section is intended to clarify that reserving transmission for existing customers
(native load) is not considered unduly discriminatory.



Study on the Benefits of Economic Dispatch (Sec. 1234). The
Secretary of Energy, in consultation with the states, is required to issue an annual
report to Congress and the states on the current status of economic dispatch.
Economic dispatch is defined as “the operation of generation facilities to produce
energy at the lowest cost to reliably serve consumers, recognizing any operational
limits of generation and transmission facilities.”
Protection of Transmission Contracts in the Pacific Northwest (Sec.
1235). FERC does not have the authority to require electric utilities in the Pacific
Northwest to convert firm transmission rights to tradable or financial rights. The
area of the Pacific Northwest is the region defined in Section 3 of the Pacific
Northwest Electric Power Planning and Conservation Act (16 U.S.C.839a) or a
portion of a state included in the geographic area proposed for a Regional
Transmission Organization in FERC Docket No. RT01-35.
Sense of Congress Regarding Locational Installed Capacity
Mechanism (Sec. 1236). It is the sense of Congress that FERC should carefully
consider the objections of the states to a proposed locational installed capacity
mechanism in New England. The objections include that a locational installed
capacity mechanism would not provide adequate assurance that necessary electric
generation capacity or reliability will be provided and it would impose a high cost on
consumers.
Subtitle D — Transmission Rate Reform
Transmission Infrastructure Investment (Sec. 1241). Within one year
of enactment, FERC is required to establish a rule to create incentive-based,
including performance-based, transmission rates. The rule is to promote reliable and
economically efficient electric transmission and generation, provide for a return on
equity that attracts new investment in transmission, encourage use of technologies
that increase the transfer capacity of existing transmission facilities, and allow for the
recovery of all prudently incurred costs that are necessary to comply with mandatory
reliability standards and those that would result from transmission siting and
construction on a National Interest Electric Transmission Corridor. FERC is directed
to implement incentive rate-making for utilities that join a Regional Transmission
Organization.
Funding New Interconnection and Transmission Upgrades (Sec.
1242). FERC may approve a participant funding plan for new transmission or for
new generator interconnection if the plan results in rates that are just and reasonable,
not unduly discriminatory or preferential, and otherwise consistent with sections 205
and 206 of the Federal Power Act.



Subtitle E — Amendments to the Public Utility Regulatory
Policies Act (PURPA)4
Net Metering and Additional Standards (Sec. 1251). For states that
have not considered implementation and adoption of net metering standards, within
two years of enactment, state regulatory authorities are required to begin considering
whether to implement net metering. This process must be completed within three
years of enactment. Net metering service is defined as service to an electric
consumer under which electric energy generated by that electric consumer from an
eligible on-site generating facility (e.g., solar or small generator) and delivered to
local distribution facilities may be used to offset electric energy provided by the
electric utility to the electric consumer during the applicable billing period. During
the same time frame, states must consider whether to implement a standard to require
electric utilities to develop a plan to minimize dependence on one fuel source. In
addition, states must consider whether to implement a requirement that electric
utilities develop and implement a 10-year plan to increase the efficiency of fossil fuel
generation.
Smart Metering (Sec. 1252). For states that have not considered
implementation and adoption of a smart metering standard, state regulatory
authorities are required issue a decision within 18 months of enactment on whether
to implement a standard for time-based rate schedules for electric utility customers.
Customers using time-based rate schedules must be provided with a time-based meter
capable of allowing utility customer to receive the time-based rate. This section5
amends the Public Utility Regulatory Policies Act of 1978 (PURPA) and requires
the Secretary of Energy to provide consumer education on advanced metering and
communications technologies, to identify and address barriers to adoption of demand
response programs, and to issue a report to Congress not later than 180 days after
enactment that identifies and quantifies the benefits of demand response. The
Secretary of Energy must provide technical assistance to regional organizations to
identify demand response potential and to develop demand response programs to
respond to peak demand or emergency needs. FERC is directed to issue an annual
report, by region, to assess demand response resources.
Cogeneration and Small Power Production Purchase and Sale
Requirements (Sec. 1253). Section 210 of PURPA required utilities to purchase
power from qualifying facilities and small power producers at a rate based on the
utilities’ avoided cost, the cost they would have incurred to generate the additional
power themselves, as determined by utility regulators.6 This section repeals the
mandatory purchase requirement under Section 210 of PURPA for new contracts if
FERC finds that a competitive electricity market exists and a qualifying facility has
access to independently administered, auction-based, day-ahead, real-time wholesale
markets and long-term wholesale markets. Qualifying facilities also need to have
access to transmission and interconnection services provided by a FERC-approved


4 P.L. 95-617
5 P.L. 95-617.
6 16 U.S.C. 824a-3.

regional transmission entity that provides nondiscriminatory treatment for all
customers. Ownership limitations under PURPA are repealed.
Background and Analysis. The oil embargoes of the 1970s created
concerns about the security of the nation’s electricity supply and led to enactment of
the Public Utility Regulatory Policies Act of 1978. For the first time, utilities were
required to purchase power from outside sources, or “qualifying facilities.” The
purchase price was set at the utilities’ avoided cost. PURPA was established in part
to augment electric utility generation with more efficiently produced electricity and
to provide equitable rates to electric consumers.
In addition to PURPA, the Fuel Use Act of 1978 (FUA) helped qualifying7
facilities (QFs) become established. Under FUA, utilities were not permitted to use
natural gas to fuel new generating facilities. QFs, which are by definition not
utilities, were able to take advantage of then-abundant natural gas as well as new
generating technology, such as combined-cycle plants that use hot gases from
combustion turbines to generate additional power. These technologies lowered the
financial threshold for entrance into the electricity generation business and shortened
the lead time for constructing new plants. FUA was repealed in 1987, but by that
time, QFs and small power producers had gained a portion of the total electricity
supply.
This influx of QF power challenged the cost-based rates that previously guided
wholesale transactions. Before implementation of PURPA, FERC approved
wholesale interstate electricity transactions based on the seller’s costs to generate and
transmit the power. Because nonutility generators typically do not have enough
market power to influence the rates they charge, FERC began approving certain
wholesale transactions whose rates were a result of a competitive bidding process.
These rates are called market-based rates.
This first incremental change to traditional electricity regulation started a
movement toward a market-oriented approach to electricity supply. Following the
enactment of PURPA, two basic issues stimulated calls for further change: whether
to encourage nonutility generation and whether to permit utilities to diversify into
nonregulated activities.
The Energy Policy Act of 1992 (EPACT)8 removed several regulatory barriers
for entry into electricity generation to increase competition of electricity supply.
However, EPACT does not permit FERC to mandate that utilities transmit exempt
wholesale generator (EWG) power to retail consumers (commonly called “retail
wheeling” or “retail competition”), an activity that remains under the jurisdiction of
state public utility commissions. PURPA began to shift more regulatory
responsibilities to the federal government, and EPACT continued that shift away
from the states by creating new options for utilities and regulators to meet electricity
demand.


7 P.L. 95-620.
8 P.L. 102-486.

Proponents of the PURPA repeal — primarily investor-owned utilities (IOUs)
located in the Northeast and in California — argued that their state regulators’
“misguided” implementation of PURPA in the early 1980s had forced them to pay
contractually high prices for power they did not need. They argued that, given the
current environment for cost-conscious competition, PURPA was outdated. Investor-
owned utility interests strongly supported the repeal of Section 210 of PURPA,
contending that PURPA’s mandatory purchase obligation was anticompetitive and
anticonsumer. 9
Opponents of mandatory purchase requirement repeal (independent power
producers, industrial power customers, most segments of the natural gas industry, the
renewable energy industry, and environmental groups) had many reasons to support
PURPA as it stood. Mainly, their argument was that PURPA introduced competition
in the electric generating sector and, at the same time, helped promote wider use of
cleaner, alternative fuels to generate electricity. Since the electric-generating sector
is not yet fully competitive, they argued, repealing PURPA would decrease
competition and impede the development of the renewable energy industry.
Additionally, opponents of the PURPA repeal argued that it would result in less
competition and greater utility monopoly control over the electric industry. Some
state regulators had expressed concern that repealing Section 210 would prevent them
from deciding matters currently under their jurisdiction.
Interconnection (Sec. 1254). Each state regulatory authority, if it has not
already done so, and each nonregulated utility must consider establishing an
interconnection standard for on-site generating facilities that request to be connected
to the local distribution facilities. Interconnection services will be offered according
to the Institute of Electrical and Electronics Engineers (IEEE) Standard 1547 for
Interconnecting Distributed Resources with Electric Power Systems. Consideration
of the standard is to commence not later than one year after enactment and be
completed not later than two years after the date of enactment.
Subtitle F — Repeal of the Public Utility Holding Company
Act of 1935 (PUHCA)10
Short Title (Sec. 1261). This subtitle is to be cited as the “Public Utility
Holding Company Act of 2005.”
Definitions (Sec. 1262). This section establishes definitions for the following
terms: affiliate, associate company, commission, company, electric utility company,
exempt wholesale generator and foreign utility company, gas utility company,
holding company, holding company system, jurisdictional rates, natural gas company,
person, public utility, public-utility company, state commission, subsidiary company,
and voting security.


9 U.S. Congress. House of Representatives. The Energy Policy Act of 2005. Hearings
before the Committee on Energy and Commerce, Subcommittee on Energy and Air Quality.
Serial No. 109-1. February 10 and February 16, 2005.
10 15 U.S.C. 79 et seq.

Repeal of the Public Utility Holding Company Act of 1935 (Sec.

1263). The Public Utility Holding Company Act of 1935 (PUHCA) is repealed.


Background and Analysis. In general, PUHCA set forth the structure of
holding companies by prohibiting all holding companies that were more than twice
removed from the operating subsidiaries. It also federally regulated holding
companies of investor-owned utilities and provided for Securities and Exchange
Commission (SEC) regulation of mergers and diversification proposals. Registered
holding companies of subsidiaries were required to have SEC approval prior to
issuing securities; all loans in intercompany financial transactions were regulated by
the SEC. A holding company could have been exempt from PUHCA if its business
operations and those of its subsidiaries occurred within one state or with a contiguous
state.
Historically, electricity service was defined as a natural monopoly, meaning that
the industry has (1) an inherent tendency toward declining long-term costs, (2) high
threshold investment, and (3) technological conditions that limit the number of
potential entrants. In addition, many regulators have considered unified control of
generation, transmission, and distribution as the most efficient means of providing
service. As a result, most people (about 75%) are currently served by a vertically
integrated, investor-owned utility.
As the electric utility industry has evolved, however, there has been a growing
belief that the historic classification of electric utilities as natural monopolies has
been overtaken by events and that market forces can and should replace some of the
traditional economic regulatory structure. For example, the existence of utilities that
do not own all of their generating facilities, primarily cooperatives and publicly
owned utilities, has provided evidence that vertical integration has not been necessary
for providing efficient electric service. Moreover, recent changes in electric utility
regulation and improved technologies have allowed additional generating capacity
to be provided by independent firms rather than utilities.
The Public Utility Holding Company Act and the Federal Power Act of 1935
(Title I and Title II of the Public Utility Act) established a regime of regulating
electric utilities that gave specific and separate powers to the states and the federal
government. A regulatory bargain was made between the government and utilities.
In exchange for an exclusive franchise service territory, utilities must provide
electricity to all users at reasonable, regulated rates.
State regulatory commissions address intrastate utility activities, including
wholesale and retail rate-making. State authority currently tends to be as broad and
as varied as the states are diverse. At the least, a state public utility commission will
have authority over retail rates, and often over investment and debt. At the other end
of the spectrum, the state regulatory body will oversee many facets of utility
operation. Despite this diversity, the essential mission of the state regulator in states
that have not restructured is the establishment of retail electric prices. This is
accomplished through an adversarial hearing process. The central issues in such
cases are the total amount of money the utility will be permitted to collect and how
the burden of the revenue requirement will be distributed among the various
customer classes (residential, commercial, and industrial).



Under the FPA, federal economic regulation addresses wholesale transactions
and rates for electric power flowing in interstate commerce. Federal regulation
follows state regulation and is premised on the need to fill the regulatory vacuum
resulting from the constitutional inability of states to regulate interstate commerce.
In this bifurcation of regulatory jurisdiction, federal regulation is limited and
conceived to supplement state regulation. FERC has the principal functions at the
federal level for the economic regulation of the electric utility industry, including
financial transactions, wholesale rate regulation, transactions involving transmission
of unbundled retail electricity, interconnection and wheeling of wholesale electricity,
and ensuring adequate and reliable service. Before enactment of P.L. 109-58, in
order to prevent a recurrence of the abusive practices of the 1920s (e.g.,
cross-subsidization, self-dealing, pyramiding), SEC regulated utilities’ corporate
structure and business ventures under PUHCA.
The electric utility industry has been in the process of transformation. During
the past two decades, there has been a major change in direction concerning
generation. First, improved technologies have reduced the cost of generating
electricity as well as the size of generating facilities. Prior preference for large-scale
— often nuclear or coal-fired — powerplants has been supplanted by a preference for
small-scale production facilities that can be brought on-line more quickly and
cheaply, with fewer regulatory impediments. Second, technological advances have
lowered the entry barrier to electricity generation and permitted nonutility entities to
build profitable facilities.
One argument for additional PUHCA change was made by electric utilities that
wanted to further diversify their assets. Under PUHCA, a holding company could
acquire securities or utility assets only if the SEC found that such a purchase would
improve the economic efficiency and service of an integrated public utility system.
It was argued that reform to allow diversification would improve the risk profile of
electric utilities in much the same way as in other businesses: the risk of any one
investment is diluted by the risk associated with all investments. Utilities also argued
that diversification would lead to better use of underutilized resources (due to the
seasonal nature of electric demand). Utility holding companies that were exempt
from SEC regulation argued that PUHCA discouraged diversification because the
SEC could have repealed their exempt status if exemption would be “detrimental to
the public interest.”11
State regulators expressed concerns that increased diversification could lead to
abuses, including cross-subsidization — a regulated company subsidizing an
unregulated affiliate. Cross-subsidization was a major argument against the creation
of exempt wholesale generators (EWGs) and reemerged as an argument against
further PUHCA change. In the case of electric and gas companies, nonutility
ventures that are undertaken as a result of diversification may benefit from the
regulated utilities’ allowed rate of return. Moneymaking nonutility enterprises would
contribute to the overall financial health of a holding company. However,


11 U.S. Congress. House of Representatives. The Energy Policy Act of 2005. Hearings
before the Committee on Energy and Commerce, Subcommittee on Energy and Air Quality.
Serial No. 109-1. February 10 and February 16, 2005.

unsuccessful ventures could harm the entire holding company, including utility
subsidiaries. In this situation, opponents feared that utilities would not be penalized
for failure in terms of reduced access to new capital, because they could increase
retail rates.
Several consumer and environmental public interest groups, as well as state
legislators, expressed concerns about the PUHCA repeal. Such groups argued that the
repeal could only exacerbate market power abuses in what they viewed as a
monopolistic industry where true competition does not yet exist.
Federal Access to Books and Records (Sec. 1264). Holding
companies and their affiliates are required to make available to FERC books and
records of affiliate transactions that FERC determines are relevant to costs incurred
by a public utility or natural gas company within the holding company system to
protect ratepayers with respect to FERC jurisdictional rates. Federal officials are
required to maintain confidentiality of such books and records. Before enactment,
registered holding companies and subsidiary companies were required to preserve
accounts, cost-accounting procedures, correspondence, memoranda, papers, and
books that the SEC deemed necessary or appropriate in the public interest or for the
protection of investors and consumers.
State Access to Books and Records (Sec. 1265). A jurisdictional state
commission may make a reasonably detailed written request to a holding company
or any associate company for access to specific books and records. The states must
safeguard against unwarranted disclosure to the public of any trade secrets or
sensitive commercial information. Response to such a request is mandatory.
Compliance with this section is enforceable in U.S. District Court. This section does
not apply to an entity that is considered to be a holding company solely by reason of
ownership of one or more qualifying facilities.
Before enactment, the Federal Power Act allowed state commissions to examine
the books, accounts, memoranda, contracts, and records of a jurisdictional electric
utility company, an exempt wholesale generator that sells to such electric utility, and
an electric utility company or holding company that is an associate company or
affiliate of an exempt wholesale generator. In issuing such an order for information,
a state commission was not required to specify which books, accounts, memoranda,
contracts, and records it was requesting.
Exemption Authority (Sec. 1266). FERC is directed to promulgate rules
within 90 days from the effective date of this section to exempt qualifying facilities,
exempt wholesale generators, and foreign utilities from the federal access to books
and records provision (Section 1264). FERC is also required to exempt books,
accounts, memoranda, and other records that are not relevant to the jurisdictional
rates of a public utility or natural gas company. Any class of transactions that is not
relevant to the jurisdictional rates of a public utility or natural gas company is also
exempt.
Affiliate Transactions (Sec. 1267). FERC retains the authority to prevent
cross-subsidization and to assure that jurisdictional rates are just and reasonable.
FERC and state commissions retain jurisdiction to determine whether associate



company activities could be recovered in rates. Before enactment of the new energy
law, the Federal Power Act required that jurisdictional rates were just and reasonable
and prohibited cross-subsidization.12
Applicability (Sec. 1268). Except as specifically noted, this subtitle does not
apply to the U.S. government, a state, or any political subdivision of the state, or
foreign governmental authority operating outside the United States.
Effect on Other Regulations (Sec. 1269). FERC or state commissions are
not precluded from exercising their jurisdiction under otherwise applicable laws to
protect utility customers.
Enforcement (Sec. 1270). FERC is given the authority to enforce
provisions under sections 306-317 of the Federal Power Act. Before enactment, the
Securities and Exchange Commission had the authority to investigate and enforce
provisions of the Public Utility Holding Company Act of 1935.
Savings Provisions (Sec. 1271). Persons may continue to participate in
legal activities in which they have been engaged or are authorized to engage in on the
effective date of this act. This subtitle would not limit the authority of FERC under
the Federal Power Act or the Natural Gas Act.13 Tax treatment for exchanges of
stock or securities under section 1081 of the Internal Revenue Service Code,
Nonrecognition of Gain or Loss on Exchanges or Distributions in Obedience to
Orders of the SEC, is not affected due to the repeal of PUHCA.
Implementation (Sec. 1272). Not later than four months after enactment,
FERC is required to promulgate regulations necessary to implement this subtitle
(excluding section 1265, which relates to state access to books and records) and
submit to Congress recommendations for technical or conforming amendments to
federal law necessary to carry out this subtitle.
Transfer of Resources (Sec. 1273). The Securities and Exchange
Commission is required to transfer all applicable books and records to FERC.
Effective Date (Sec. 1274). Six months after enactment, this subtitle will
take effect. This effective date does not apply to Section 1282 (implementation). If
any FERC rule-making that modifies the standards of conduct governing entities that
own, operate, or control facilities for transmission of electricity in interstate
commerce or transportation of natural gas in interstate commerce takes effect prior
to the effective date of this section, any action taken by a public utility company or
utility holding company to comply with the FERC requirements will not subject these
companies to any regulatory requirement under PUHCA.
Service Allocation (Sec. 1275). FERC is required to review and authorize
cost allocations for nonpower goods or administrative or management services
provided by an associate company that was organized specifically for the purpose of


12 16 U.S.C. 791a et seq.
13 15 U.S.C. 717 et seq.

providing such goods or services. This section does not preclude FERC or state
commissions from exercising their jurisdiction under other applicable laws with
respect to review or authorization of any costs. FERC is required to issue rules
within four months of enactment to exempt from the section any company and
holding company system if operations are confined substantially to a single state.
Authorization of Appropriations (Sec. 1276). Necessary funds to carry
out this subtitle are authorized to be appropriated.
Conforming Amendments to the Federal Power Act (Sec. 1277). The
Federal Power Act is amended to reflect the changes to the Public Utility Holding
Company Act of 1935.
Subtitle G — Market Transparency, Enforcement, and
Consumer Protection
Electricity Market Transparency (Sec. 1281). FERC is directed to
facilitate price transparency in wholesale electric markets. FERC may prescribe rules
to provide on a timely basis information about the availability and prices of
wholesale electric energy and transmission service to FERC, state commissions,
buyers and sellers of wholesale electric energy, users of transmission services, and
the public. FERC is directed to rely on existing price publishers and providers of
trade processing services the maximum extent possible. However, FERC may
establish an electronic information system if it determines that existing price
information is not adequate. Any rules promulgated by FERC will exempt from
disclosure any information that would be detrimental to the operation of an effective
market or jeopardize system security. Within 180 days of enactment, FERC must
enter into a memorandum of understanding (MOU) with the Commodity Futures
Trading Commission to ensure coordination of information requests to markets.
Entities with a de minimis market presence are not required to comply with the
reporting requirements of the section. No one will be subject to civil penalties for
any violation of the reporting requirements that occur more than three years before
the date on which the person has provided notice of the proposed penalty. This
would not apply to entities that have engaged in fraudulent market manipulation
activities. The section does not apply to the area of the Electric Reliability Council
Texas.
False Statements (Sec. 1282). The Federal Power Act is amended to
expressly prohibit any entity from willingly and knowingly reporting false
information to a federal agency relating to the price of electricity sold at wholesale
or the availability of transmission capacity.
Existing mail fraud laws, in part, apply to use of the mail for the purpose of
executing, or attempting to execute, a scheme or artifice to defraud, or for obtaining
money or property by false or fraudulent pretenses, representations, or promises.
Wire fraud statutes cover use of wire, radio, or television communication in interstate
or foreign commerce to transmit or to cause to be transmitted, any writings, science,
signals, pictures, or sounds for the purpose of executing a scheme or artifice to



defraud, or to obtain money or property by means of false or fraudulent pretenses,
representations, or promises.
Market Manipulation (Sec. 1283). Amends the Federal Power Act to
expressly prohibit any entity, in connection with the purchase or sale of FERC
jurisdictional electric energy or transmission services, from directly or indirectly
using any manipulative or deceptive device or contrivance.
Enforcement (Sec. 1284). The Federal Power Act is amended to allow
electric utilities to file complaints with FERC and to allow complaints to be filed
against transmitting utilities. Criminal and civil penalties under the Federal Power
Act are increased. Criminal penalties may not exceed $1 million and/or five years’
imprisonment. In addition, a fine of $25,000 may be imposed. A civil penalty not
exceeding $1 million per day per violation may be assessed for violations of sections
211, 212, 213, or 214 of the Federal Power Act. Before enactment of the new energy
law, criminal penalties could not have exceeded $5,000 and/or two years’
imprisonment. An additional fine of $500 could have been imposed. A civil penalty
not exceeding $10,000 per day per violation could have been assessed for violations
of sections 211, 212, 213, or 214 of the Federal Power Act.
Refund Effective Date (Sec. 1285). Section 206(b) of the Federal Power
Act is amended to allow the effective date for refunds to begin at the time of the
filing of a complaint with FERC, but not later than five months after such a filing.
If FERC does not make its decision within the time frame provided, FERC would be
required to state its reasons for not acting in the provided time frame for the decision.
Refund Authority (Sec. 1286). Any entity that is not a public utility
(including an entity referred to under Section 201(f) of the Federal Power Act) and
enters into a short-term sale of electricity is subject to the FERC refund authority. A
short-term sale includes any agreement to the sale of electric energy at wholesale that
is for a period of 31 days or less. This section does not apply to electric cooperatives
or any entity that sells less than 8 million megawatt-hours of electricity per year.
FERC is given refund authority over voluntary short-term sales of electricity by
Bonneville Power Administration if the rates charged are unjust and unreasonable.
FERC is given authority over all power marketing administrations and the Tennessee
Valley Authority to order refunds to achieve just and reasonable rates. Before
enactment, Section 201(f) of the Federal Power Act exempted government entities
from FERC rate regulation.
Consumer Privacy and Unfair Trade Practices (Sec. 1287). The
Federal Trade Commission is authorized to issue rules to prohibit slamming and
cramming. Slamming occurs when an electric utility switches a customer’s electric
provider without the consumer’s knowledge. Cramming occurs when an electric
utility adds additional services and charges to a customer’s account without
permission of the customer. If the Federal Trade Commission determines that a
state’s regulations provide equivalent or greater protection, then the state regulations
would apply in lieu of regulations issued by the Federal Trade Commission.
Authority of Court to Prohibit Individuals from Serving As Officers,
Directors, and Energy Traders (Sec. 1288). The court is allowed to prohibit



any person who is found to have violated Section 221 of the Federal Power Act
(Prohibition on Filing False Information) from acting as an officer or director of an
electric utility or engaging in the business of purchasing or selling FERC
jurisdictional electric energy or transmission services.
Merger Review Reform (Sec. 1289). The Federal Power Act is amended
to give FERC approval authority over the acquisition of securities and the merger,
sale, lease, or disposition of facilities under FERC’s jurisdiction with a value in
excess of $10 million. FERC is required to give state public utility commissions and
governors reasonable notice in writing of the acquisition of securities and the
merger, sale, lease, or disposition of facilities under FERC’s jurisdiction. FERC
must approve the proposed change of control, acquisition, disposition, or
consolidation if it finds that the proposed transaction is consistent with the public
interest and will not result in cross-subsidization of a nonutility associate company
or the pledge or encumbrance of utility assets for the benefit of an associate company,
unless it is consistent with the public interest. If FERC does not act within 180 days
of an application, the application will be deemed granted unless FERC finds that
further consideration is required. This section takes effect six months after
enactment. Before enactment, under section 203(a) of the Federal Power Act, FERC
review of asset transfers applied to transactions valued at $50,000 or more.
Relief for Extraordinary Violations (Sec. 1290). This section applies to
contracts for wholesale electricity within the Western Interconnection prior to June
20, 2001, for which FERC has found that the wholesale power sellers manipulated
that electricity market, resulting in unjust and unreasonable rates, and FERC has
revoked the seller’s authority to sell at market-based rates. For these contracts, FERC
may determine whether termination payments for power not delivered by the seller
are unlawful on the grounds that the contract is unjust and unreasonable or contrary
to the public interest. This applies only to cases still pending before FERC and not
previously settled.
Subtitle H — Definitions
Definitions (Sec. 1291). The definitions for electric utility and transmitting
utility under the Federal Power Act are amended. Definitions for the following terms
are added to the Federal Power Act: electric cooperative, regional transmission
organization, independent system operator, and transmission organization.
Section 201(f) of the Federal Power Act is amended to add that, in addition to
a political subdivision of a state, an electric cooperative that receives financing under
the Rural Electrification Act of 1936 or an electric cooperative that sells less than

4,000,000 MW-hours of electricity per year is not subject to FERC rate regulation.


Subtitle I — Technical and Conforming Amendments
Conforming Amendments (Sec. 1295). The Federal Power Act is
amended to conform with this section.



Subtitle J — Economic Dispatch
Economic Dispatch (Sec. 1298). FERC is directed to convene regional
boards to study “security constrained economic dispatch.” A member of FERC will
chair each regional joint board, composed of a representative from each state. Within
one year of enactment, FERC is required to submit a report to Congress on the
recommendations of the joint regional boards. This section does not define “security
constrained economic dispatch,” but it generally means a dispatch system that
ensures that all normal and contingency limits of the system are simultaneously met
under a base case with one contingency: the loss of a critical network element (n-1
security analysis).
Title XVIII — Studies
Effect of Electrical Contaminants Unreliability of Energy Production
Systems (Sec. 1822). Within 180 days after enactment, the Secretary of Energy
will enter into a contract with the National Academy of Sciences (Academy), under
which the Academy will determine the effect that electrical contaminants may have
on the reliability of energy production systems, including nuclear energy.
Final Action on Refunds for Excessive Charges (Sec. 1824). FERC
is directed to complete its investigation into the unjust and unreasonable charges
incurred by California during the 2000-2001 electricity crisis. A report to Congress
will be submitted by December 31, 2005, that describes FERC’s actions and a
timetable for further actions. This was submitted to Congress on December 27,

2005.14


Study the Benefits of Economic Dispatch (Sec. 1832). The Secretary
of Energy, in consultation with the states, must study economic dispatch and issue
an annual report to Congress and the states. Economic dispatch is defined as “the
operation of generation facilities to produce energy at the lowest cost to reliably serve
consumers, recognizing any operational limits of generation and transmission
facilities.”
Transmission System Monitoring (Sec. 1839). Within six months after
enactment, the Secretary of Energy and FERC will study and report to Congress on
what would be involved in providing all transmission system owners and Regional
Transmission Organizations with real-time transmission line operating status.


14 This report is available at [http://www.ferc.gov/legal/maj-ord-reg/fed-sta/ene-pol-act.asp].
Website last checked by CRS on January 24, 2006.