# Federal Register / Vol. 72, No. 146 / Tuesday, July 31, 2007 / Notices

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URL: https://www.frixlaw.com/law-library/documents/agency%3Aferc%3Ab289bf89821aafe0

## Record

- **Collection:** Agency decision
- **Document type:** Agency decision

## Text

41744

Federal Register / Vol. 72, No. 146 / Tuesday, July 31, 2007 / Notices

Note: all times are local.
[FR Doc. E7–14742 Filed 7–30–07; 8:45 am]
BILLING CODE 6717–01–P

DEPARTMENT OF ENERGY
Federal Energy Regulatory
Commission
[Docket No. PL07–2–000]

Composition of Proxy Groups for
Determining Gas and Oil Pipeline
Return on Equity
July 19, 2007.
AGENCY: Federal Energy Regulatory

Commission.

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ACTION: Proposed Policy Statement.
SUMMARY: The Federal Energy
Regulatory Commission is proposing to
modify its current policy regarding the
composition of proxy groups used to
determine return on equity for natural
gas and oil pipelines under the
Discounted Cash Flow Methodology.
Under the proposed policy statement,
the Commission would permit Master
Limited Partnerships (MLPs) to be
included in the proxy group, subject to
certain conditions. The Commission
proposes to leave to individual cases the
determination of the specific MLPs to be
included in the proxy group used to
determine return on equity in that case.
DATES: Initial comments are due August
30, 2007. Reply comments are due
August 30, 2007.
ADDRESSES: You may submit comments,
identified in Docket No. PL07–2–000, by
any of the following methods:
1. Agency Web Site: http://
www.ferc.gov. The Commission accepts
most standard word processing formats
and commentors may attach additional
filed with supporting information in
certain other file formats. Commentors
filing electronically do not need to make
a paper filing.
2. Mail/Hand Delivery: Commentors
unable to file comments electronically
must mail or hand-deliver an original
and 14 copies of their comments to:
Federal Energy Regulatory Commission,
Office of the Secretary, 888 First Street,
NE., Washington, DC 20426.
FOR FURTHER INFORMATION CONTACT: John
M. Robinson, Office of the General
Counsel, Federal Energy Regulatory
Commission, 888 First Street, NE.,
Washington, DC 20426, 202–502–6808,
John.Robinson@ferc.gov.

Before Commissioners: Joseph T. Kelliher,
Chairman; Suedeen G. Kelly, Marc Spitzer,
Philip D. Moeller, and Jon Wellinghoff.

1. In this proposed Policy Statement,
the Commission is proposing to update

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its standards concerning the
composition of the proxy groups used to
decide the return on equity (ROE) of
natural gas and oil pipelines. Firms
engaged in the pipeline business are
increasingly organized as master limited
partnerships (MLPs). Therefore, the
Commission proposes to modify its
current policy regarding the
composition of proxy groups to allow
MLPs to be included in the proxy group.
This proposed Policy Statement
explains the standards that the
Commission would require to be met in
order for an MLP to be included in the
proxy group. The Commission proposes
to apply its final Policy Statement to all
gas and oil pipeline rate cases that have
not completed the hearing phase as of
the date the Commission issues its final
Policy Statement. The Commission
intends to decide on a case-by-case basis
whether to apply the final Policy
Statement in cases that have completed
the hearing phase. Finally, the
Commission is requesting comments on
this proposed Policy Statement. Initial
comments are due 30 days after
publication of this order in the Federal
Register, with reply comments due 50
days after publication in the Federal
Register.
I. Background
2. Since the 1980s, the Commission
has used a Discounted Cash Flow (DCF)
model to develop a range of returns
earned on investments in companies
with corresponding risks for
determining the ROE for natural gas and
oil pipelines. The DCF model was
originally developed as a method for
investors to estimate the value of
securities, including common stocks. It
is based on ‘‘the premise that a stock is
worth the present value of its future
cash flows, discounted at a market rate
commensurate with the stock’s risk.’’ 1
Unlike investors, the Commission uses
the DCF model to determine the ROE to
be included in the pipeline’s rates,
rather than to estimate a stock’s value.
Therefore, the Commission solves the
DCF formula for the discount rate,
which represents the rate of return that
an investor requires in order to invest in
a firm. Under the resulting DCF formula,
ROE equals current dividend yield
(dividends divided by share price) plus
the projected future growth rate of
dividends.
3. The Commission uses a two-step
procedure for determining the constant
growth of dividends: averaging short1 Ozark Gas Transmission System, 68 FERC ¶
61,032 at 61,104, n. 16 (1994).

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term and long-term growth estimates.2
Security analysts’ five-year forecasts for
each company in the proxy group, as
published by Institutional Brokers
Estimate System (IBES), are used for
determining growth for the short term;
long-term growth is based on forecasts
of long-term growth of the economy as
a whole, as reflected in the Gross
Domestic Product. The short-term
forecast receives a 2⁄3 weighting and the
long-term forecast receives a 1⁄3
weighting in calculating the growth rate
in the DCF model.3
4. Most gas pipelines are whollyowned subsidiaries and their common
stock is not publicly traded, and this is
also true for some jurisdictional oil
pipelines. Therefore, the Commission
uses a proxy group of firms with
corresponding risks to set a range of
reasonable returns for both natural gas
and oil pipelines. The Commission then
assigns the pipeline a rate within that
range or zone, to reflect specific risks of
that pipeline as compared to the proxy
group companies.4
5. The Commission historically
required that each company included in
the proxy group satisfy the following
three standards.5 First, the company’s
stock must be publicly traded. Second,
the company must be recognized as a
natural gas or oil pipeline company and
its stock must be recognized and tracked
by an investment information service
such as Value Line. Third, pipeline
operations must constitute a high
proportion of the company’s business.
Until the Commission’s 2003 decision
in Williston Basin Interstate Pipeline
Co.,6 the third standard could only be
satisfied if a company’s pipeline
business accounted for, on average, at
least 50 percent of a company’s assets or
operating income over the most recent
three-year period.
2 Northwest Pipeline Co., 71 FERC ¶ 61,309 at
61,989–92 (1995) (Opinion No. 396), 76 FERC ¶
61,068 (1996) (Opinion No. 396–A), 79 FERC ¶
61,309 (1997) (Opinion No. 396–B), reh’g denied, 81
FERC ¶ 61,036 (1997) (Opinion No. 396–C);
Williston Basin Interstate Pipeline Co., 79 FERC ¶
61,311, order on reh’g, 81 FERC ¶ 61,033 (1997),
aff’d in relevant part, Williston Basin Interstate
Pipeline Co., 165 F.3d 54 (D.C. Cir. 1999) (Williston
Basin).
3 The Commission presumes that existing
pipelines fall within a broad range of average risk,
and thus generally sets pipelines’ return at the
median of the range. Transcontinental Gas Pipe
Line Corp., 84 FERC ¶ 61,084 at 61,423–4 (1998)
Opinion No. 414–A, reh’g, 85 FERC ¶ 61,323 (1998)
(Opinion No. 414–B), aff’d North Carolina Utilities
Commission v. FERC, 340 U.S. App. D.C. 183 (D.C.
Cir) (unpublished opinion).
4 Williston Basin at 57 (citation omitted).
5 Transcontinental Gas Pipe Line Corp., 90 FERC
¶ 61,279 at 61,933 (2000).
6 Williston Basin Interstate Pipeline Company,
104 FERC ¶ 61,036 at P 35, n. 46 (2003).

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Federal Register / Vol. 72, No. 146 / Tuesday, July 31, 2007 / Notices
6. As a result of mergers, acquisitions,
and other changes in the natural gas
industry, fewer and fewer interstate
natural gas companies have satisfied the
third requirement. Thus, in Williston,
the Commission relaxed this
requirement for the natural gas proxy
group. Instead, the Commission
approved a pipeline’s proposal to use a
proxy group based on the corporations
listed in the Value Line Investment
Survey’s list of diversified natural gas
firms that own Commission-regulated
natural gas pipelines, without regard to
what portion of the company’s business
comprises pipeline operations.
7. In HIOS 7 and Kern River, the only
fully litigated section 4 rate cases
decided since Williston, the
Commission again drew the proxy group
companies from the same Value Line
list. When those cases were litigated,
there were six such companies: Kinder
Morgan Inc., the Williams Companies
(Williams), El Paso Natural Gas
Company (El Paso), Equitable
Resources, Inc., Questar Corporation,
and National Fuel Gas Corporation. The
Commission excluded Williams and El
Paso on the ground that their financial
difficulties had lowered their ROEs to a
level only slightly above the level of
public utility debt, and the Commission
stated that investors cannot be expected
to purchase stock if lower risk debt has
essentially the same return. This left a
four-company proxy group, three of
whose members derived more revenue
from the distribution business, rather
than the pipeline business. In Kern
River, the Commission adjusted the
pipeline’s return on equity 50 basis
points above the median in order to
account for the generally higher risk
profile of natural gas pipeline
operations as compared to distribution
operations.
8. In both Kern River and HIOS, the
Commission rejected pipeline proposals
to include MLPs in the proxy group.
The pipelines contended that MLPs
have a much higher percentage of their
business devoted to pipeline operations,
than most of the corporations that the
Commission currently includes in the
proxy group.
9. Unlike corporations, MLPs
generally distribute most available cash
flow to the general and limited partners
in the form of quarterly distributions.
Most MLP agreements define ‘‘available
cash flow’’ as (1) Net income (gross
revenues minus operating expenses)
plus (2) depreciation and amortization,
minus (3) capital investments the
7 High Island Offshore System, L.L.C., 110 FERC
¶ 61,043, reh’g denied, 112 FERC ¶ 61,050 (2005),
appeal pending.

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partnership must make to maintain its
current asset base and cash flow
stream.8 Depreciation and amortization
may be considered a part of ‘‘available
cash flow,’’ because depreciation is an
accounting charge against current
income, rather than an actual cash
expense. As a result, the MLP’s cash
distributions normally include not only
the net income component of ‘‘available
cash flow,’’ but also the depreciation
component. This means that, in contrast
to a corporation’s dividends, an MLP’s
cash distributions generally exceed the
MLP’s reported earnings. Moreover,
because of their high cash distributions,
MLPs usually finance capital
investments required to significantly
expand operations or to make
acquisitions through debt or by issuing
additional units rather than through
retained cash, although the general
partner has the discretion to do so.
10. In rejecting the pipelines’
proposals in HIOS and Kern River to
include MLPs in the proxy group, the
Commission made clear that it was not
making a generic finding that MLPs
cannot be considered for inclusion in
the proxy group if a proper evidentiary
showing is made.9 However, the
Commission pointed out that data
concerning dividends paid by the proxy
group members is a key component in
any DCF analysis, and expressed
concern that an MLP’s cash
distributions to its unit holders may not
be comparable to the corporate
dividends the Commission uses in its
DCF analysis. In Kern River, the
Commission explained its concern as
follows:
Corporations pay dividends in order
to distribute a share of their earnings to
stockholders. As such, dividends do not
include any return of invested capital to
the stockholders. Rather, dividends
represent solely a return on invested
capital. Put another way, dividends
represent profit that the stockholder is
making on its investment. Moreover,
corporations typically reinvest some
earnings to provide for future growth of
earnings and thus dividends. Since the
return on equity which the Commission
awards in a rate case is intended to
permit the pipeline’s investors to earn a
profit on their investment and provides
funds to finance future growth, the use
of dividends in the DCF analysis is
entirely consistent with the purpose for
which the Commission uses that
8 The definition of available cash may also net out
short term working capital borrowings, the
repayment of capital expenditures, and other
internal items.
9 Kern River Gas Transmission Company, 117
FERC ¶ 61,077 (2006) (Opinion No. 486) at P 147,
reh’g pending.

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analysis. By contrast, as Kern River
concedes, the cash distributions of the
MLPs it seeks to add to the proxy group
in this case include a return of invested
capital through an allocation of the
partnership’s net income. While the
level of an MLP’s cash distributions may
be a significant factor in the unit
holder’s decision to invest in the MLP,
the Commission uses the DCF analysis
solely to determine the pipeline’s return
on equity. The Commission provides for
the return of invested capital through a
separate depreciation allowance. For
this reason, to the extent an MLP’s
distributions include a significant return
of invested capital, a DCF analysis based
on those distributions, without any
adjustment, will tend to overstate the
estimated return on equity, because the
‘dividend’ would be inflated by cash
flow representing return of equity,
thereby overstating the earnings the
dividend stream purports to reflect.10
11. The Commission stated that it
could nevertheless consider including
MLPs in the proxy group in a future
case, if the pipeline presented evidence
addressing these concerns. The order
suggested that such evidence might
include some method of adjusting the
MLPs’ distributions to make them
comparable to dividends, a showing that
the higher ‘‘dividend’’ yield of the MLP
was offset by a lower long-term growth
projection, or some other explanation
why distributions in excess of earnings
do not distort the DCF results for the
MLP in question. However, the
Commission concluded that Kern River
had not presented sufficient evidence to
address these issues, and that the record
in that case did not support including
MLPs in the proxy group.
12. In addition, Kern River pointed
out that the traditional DCF model only
incorporates growth resulting from the
reinvestment of earnings, not growth
arising from external sources of
capital.11 Therefore, the Commission
stated that if growth forecasted for an
MLP comes from external capital, it is
necessary either (1) to explain why the
external sources of capital do not distort
the DCF results for that MLP or (2)
propose an adjustment to the DCF
analysis to eliminate any distortion. The
Commission’s orders in HIOS reached
the same conclusions.
13. In some oil pipeline rate cases
decided before HIOS and Kern River, the
Commission included MLPs in the
proxy group used to determine oil
pipeline return on equity on the ground
that there were no corporations
available for use in the oil proxy
10 Id. at P 149–50.
11 Id. at P 152.

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group.12 In those cases, no party raised
any issue concerning the comparability
of an MLP’s cash distribution to a
corporation’s dividend. However, that
issue did arise in the first oil pipeline
case decided after HIOS and Kern River,
involving SFPP’s Sepulveda Line.13 The
Commission approved inclusion of
MLPs in the proxy group in that case on
the grounds that the MLPs in question
had not made distributions in excess of
earnings. The Sepulveda Line order
therefore analyzed the five MLPs that
have been used to determine SFPP’s
ROE: Buckeye Partners, L.P., Enbridge
Energy Partners, L.P., Enron Gas Liquids
(Enron),14 TEPPCO Partners, L.P., and
Kaneb Partners, L.P. (later Valero
Partners), now NuStar Energy, L.P. The
order reviewed each entity for the year
1996 and the previous four years, and
held that four of the firms had had
income (earnings) in excess of
distributions and that their incomes
(earnings) were stable over that period
with minor exceptions. The order found
these facts sufficient to address the
concerns expressed in HIOS and Kern
River. The fifth firm, Enron, had
distributions in excess of income
(earnings) in four of the five years.
While the Commission did not preclude
use of such MLPs, Enron did not meet
the HIOS test and was excluded as
unrepresentative.

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II. Discussion
14. As discussed below, the
Commission proposes to permit
inclusion of MLPs in a proxy group.
However, the Commission proposes to
cap the ‘‘dividend’’ used in the DCF
analysis at the pipeline’s reported
earnings, thus adjusting the amount of
the distribution to be included in the
DCF model. The Commission would
leave to individual cases the
determination of which MLPs and
corporations should actually be
included in the natural gas or oil proxy
group. However, participants in these
cases should include as much
information as possible regarding the
business profile of the firms they
propose to include in the proxy group,
for example, based on gross income, net
income, or assets.
15. The Supreme Court has stated that
‘‘the return to the equity owner should
be commensurate with the return on
investments in other enterprises having
corresponding risks. That return,
moreover, should be sufficient to assure
12 SFPP, L .P., 86 FERC ¶ 61,022 at 61,099 (1999).
13 SFPP, L.P., 117 FERC ¶ 61,285 (2006) (SFPP
Sepulveda order), rehearing pending.
14 Enron Gas Liquids was not affiliated with
Enron, Inc. at that time, but was a former affiliate
that was spun off in the early 1990’s.

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confidence in the financial integrity of
the enterprise, so as to maintain its
credit and to attract capital.’’ 15 The
Commission is concerned that its
current approach to determining the
composition of the proxy group for
determining gas and oil pipeline return
on equity is, or will, require the use of
firms which are less and less
representative of either natural gas or oil
pipeline business risk.
16. As has been discussed, there are
fewer and fewer publicly traded
diversified natural gas corporations that
have interstate gas pipelines as their
predominant business line, whether this
is measured on a revenue, income, or
asset basis. As such, there are fewer
diversified natural gas companies
available for inclusion in a natural gas
pipeline proxy group which may
reasonably be considered representative
of the risk profile of a natural gas
pipeline firm. Moreover, at this point
the only publicly traded oil pipeline
firms are controlled by MLPs, which
makes the issue of a representative
proxy group more acute.
17. Cost of service ratemaking
requires that the firms in the proxy
group be of comparable risk to the firm
whose equity cost of capital is at issue
in a particular rate proceeding. If the
proxy group is less than clearly
representative, this may require the
Commission to adjust for the difference
in risk by adjusting the equity cost-ofcapital, a difficult undertaking requiring
detailed support from the contending
parties and detailed case-by-case
analysis by the Commission. Expanding
a proxy group to include MLPs whose
business is more narrowly focused on
pipeline activities would help
ameliorate this problem. Thus,
including MLP natural gas pipelines in
the equity proxy group should reduce
the need to make adjustments since the
proxy group is more likely to contain
firms that are representative of the
regulated firm whose rates are at issue.
Including MLPs will also recognize the
trend to greater use of MLPs in the
natural gas pipeline industry and
address the reality of the oil pipeline
industry structure.
18. The Commission’s primary
concern about including MLPs in the
proxy group has arisen from the
interaction between use of the DCF
analysis to determine return on capital
while relying on a depreciation
allowance for return of capital. The
Commission permits a pipeline to
recover through its rates both a return
15 FPC v. Hope Natural Gas Co., 320 U.S. 591
(1944); Bluefield Water Works & Improvement Co.
v. Public Service Comm’n, 262 U.S. 679 (1923).

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on equity and a return of invested
capital. The Commission uses the DCF
analysis solely to determine the return
on equity component of the cost-ofservice. The Commission provides for
the return of invested capital through a
separate depreciation allowance. Given
the purpose for which the Commission
uses the DCF analysis, the cash flows
included in that analysis must be
limited to cash flows which may
reasonably be considered to reflect a
return on equity. Such cash flows
include that portion of an MLP’s cash
distribution derived from net income, or
earnings.
19. To the extent an MLP makes
distributions in excess of earnings, it is
able to do so because partnership
agreements define ‘‘cash available for
distribution’’ to include depreciation.
This enables the MLP to make cash
distributions that include return of
equity, in addition to return on equity.
However, because the Commission
includes a separate depreciation
allowance in the pipeline’s cost-ofservice, a DCF analysis including cash
flows attributable to depreciation would
permit the pipeline to double recover its
depreciation expense, once through the
depreciation allowance and once
through an inflated ROE. Adjusting an
MLP’s cash distribution to exclude that
portion of the distribution in excess of
earnings addresses this problem.
20. The Commission recognizes that it
raised several concerns in Kern River as
to whether adjusting the MLP’s cash
distribution down to the level of its
earnings would be sufficient to
eliminate the distorting effects of
including MLPs in the proxy group. The
Commission pointed out that
corporations generally do not pay out all
of their earnings in dividends, but retain
some earnings in order to generate
future growth. The Commission also
suggested that the DCF model is
premised on growth in dividends
deriving from reinvestment of current
earnings, and does not incorporate
growth from external sources, such as
issuing debt or additional stock.
21. The Commission believes that
these concerns should not render
unreliable a DCF analysis using the
adjusted MLP results. The market data
for the MLPs used in the DCF analysis
should itself correct for any distortions
remaining after the adjustment to the
cash distribution described above. For
example, the IBES growth projections
represent an average of the growth
projections by professionals whose
business is to advise investors.16 The
level of an MLP’s cash distributions as
16 Opinion No. 414–B, 85 FERC at 62,268–70.

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Federal Register / Vol. 72, No. 146 / Tuesday, July 31, 2007 / Notices
compared to its earnings is a matter of
public record and thus known to the
security analysts making the growth
forecasts used by IBES. Therefore, the
security analysts must be presumed to
take those distributions into account in
making their growth forecasts for the
MLP. To the extent an MLP’s relatively
high cash distributions reduce its
growth prospects that should be
reflected in a lower growth forecast,
which would offset the MLP’s higher
‘‘dividend’’ yield.
22. In order to test the validity of this
assumption, the Commission reviewed
the most recent IBES growth forecasts
for five diversified energy companies
and six MLPs in the natural gas
business. The average IBES forecast for
the corporations is 9 percent, while the
average IBES forecast for the MLPs is
6.17 percent, or nearly 300 basis points
lower.17 Thus, the security analysts do
project lower growth rates for the MLPs
than for the corporations.
23. In addition, the fact MLPs may
rely upon external borrowings and/or
equity issuances to generate growth is
not a reason to exclude them from the
proxy group. Most pipelines organized
as corporations also use external
borrowings and to some extent equity
issuances. To the extent that gas or oil
pipelines are controlled by diversified
energy companies with unregulated
assets (either federal or state), the
financial practices may be the same,
although perhaps not as highly
leveraged, and the results are likewise
reflected in the IBES projections. A
prudent investor deciding whether to
invest in a security will reasonably
consider all factors relevant to assessing
the value of that security. The potential
effect of future borrowings or equity
issuances on share values of either
MLPs or corporations is one such factor.
Since a DCF analysis is a method for
investors to estimate the value of
securities, it follows that such an
analysis may reasonably take into
account potential growth from external
capital.
24. The Commission does, however,
recognize that an MLP’s lack of retained

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17 The IBES forecasts were prepared as of May 31,

2007 applying the current DCF model for the
corporate sample and using distributions capped at
earnings for the MLPs. Thus the short term growth
rates for the five diversified gas corporations were:
(1) National Fuel Gas Corporation, 5 percent; (2)
Questar Corporation, 9 percent; (3) Oneok, Inc., 9
percent; (4) Equitable Resources Inc., 10 percent;
and (5) Williams Companies, 12 percent. The short
term growth rates for the six gas MLPs were: (1)
Oneok Partners, L.P., 5 percent; (2) TEPPCO
Partners, L.P., 5 percent; (3) TC Pipelines, L.P., 5
percent; (4) Boardwalk Pipeline Partners, L.P., 7
percent, (5) Kinder Morgan Energy Partners, L.P., 7
percent, and (6) Enterprise Products Partners, L.P.,
8 percent.

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earnings may render cash distributions
at their current level unsustainable, and
thus still unsuitable for inclusion in the
DCF analysis. Therefore, the
Commission intends to require
participants proposing to include MLPs
in the proxy group to provide a multiyear analysis of past earnings. An
analysis showing that the MLP does
have stable earnings would support a
finding that the cash to be included in
the DCF calculation is likely to be
available for distribution, thus
replicating the requirement of the
corporate model of a stable dividend.
III. Procedure for Comments
25. The Commission invites interested
persons to submit written comments on
its proposed policy to permit the
inclusion of MLPs in the proxy group to
be used to determine the equity cost of
capital of natural gas and oil pipelines.
The comments may include alternative
proposals for determining a
representative proxy group given that
(1) Few natural gas companies meet the
Commission’s traditional standards for
inclusion in the proxy group, and (2) the
only publicly traded oil pipeline firms
available for inclusion in the proxy
group are controlled by MLPs.
Comments may also address the
analysis advanced in this proposed
policy statement, alternative methods
for adjusting the amount of the MLP’s
distribution to be included the DCF
analysis, and the relevance of the
stability of MLP earnings.
26. Comments are due 30 days from
the date of publication in the Federal
Register and reply comments are due 50
days from the date of publication in the
Federal Register. Comments must refer
to Docket No. PL07–2–000, and must
include the commentor’s name, the
organization it represents, if applicable,
and its address. To facilitate the
Commission’s review of the comments,
commentors are requested to provide an
executive summary of their position.
Additional issues the commentors wish
to raise should be identified separately.
The commentors should double space
their comments.
27. Comments may be filed on paper
or electronically via the eFiling link on
the Commission’s Web site at: http://
www.ferc.gov. The Commission accepts
most standard word processing formats
and commentors may attach additional
files with supporting information in
certain other file formats. Commentors
filing electronically do not need to make
a paper filing. Commentors that are not
able to file comments electronically
must send an original and 14 copies of
their comments to: Federal Energy
Regulatory Commission, Office of the

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Secretary, 888 First Street, NE.,
Washington DC 20426.
28. All comments will be placed in
the Commission’s public files and may
be viewed, printed, or downloaded
remotely as described in the Document
Availability section below. Commentors
are not required to serve copies of their
comments on other commentors.
IV. Document Availability
29. In addition to publishing the full
text of this document in the Federal
Register, the Commission provides all
interested persons an opportunity to
view and/or print the contents of this
document via the Internet through the
Commission’s Home Page (http://
www.ferc.gov) and in the Commission’s
Public Reference Room during normal
business hours (8:30 a.m. to 5 p.m.
Eastern time) at 888 First Street, NE.,
Room 2A, Washington, DC 20426.
30. From the Commission’s Home
Page on the Internet, this information is
available in the Commission’s document
management system, e-Library. The full
text of this document is available on
eLibrary in PDF and Microsoft Word
format for viewing, printing, and/or
downloading. To access this document
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By the Commission.
Kimberly D. Bose,
Secretary.
[FR Doc. E7–14708 Filed 7–30–07; 8:45 am]
BILLING CODE 6717–01–P

ENVIRONMENTAL PROTECTION
AGENCY
[EPA–HQ–OAR–2007–0176; FRL–8448–2]

Agency Information Collection
Activities; Proposed Collection;
Comment Request; EPA ICR No.
1591.24, OMB Control No. 2060–0277
AGENCY: Environmental Protection

Agency.
ACTION: Notice.
SUMMARY: In compliance with the
Paperwork Reduction Act (PRA) (44
U.S.C. 3501 et seq.), this document
announces that EPA is planning to

E:\FR\FM\31JYN1.SGM

31JYN1

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Source: Frix Law Library, https://www.frixlaw.com/law-library/documents/agency%3Aferc%3Ab289bf89821aafe0. Public record. Not legal advice.