30-day Notice in Fed. Reg.

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Phone: 207 990 5600 Extension 121
Fax: 207 990 5602
E-mail: [email protected]

electronically or in paper format. Those
persons filing electronically do not need
to make a paper filing. Documents filed
electronically via the Internet must be
Signed,
prepared in an acceptable filing format
Duane A. Hallowell,
and in compliance with the Federal
President and CEO
Energy Regulatory Commission
Date:
lllllllllllllllllllll submission guidelines. Complete filing
instructions and acceptable filing
Joseph M Gross,
formats are available at http://
Design Engineer
www.ferc.gov/help/submission-guide/
Date:
lllllllllllllllllllll electronic-media.asp. To file the
document electronically, access the
[FR Doc. E9–28694 Filed 12–1–09; 8:45 am]
Commission’s Web site and click on
BILLING CODE 6450–01–P
Documents & Filing, E–Filing (http://
www.ferc.gov/docs-filing/efiling.asp),
and then follow the instructions for
DEPARTMENT OF ENERGY
each screen. First-time users will have
to establish a user name and password.
Federal Energy Regulatory
The Commission will send an automatic
Commission
acknowledgement to the sender’s e-mail
[Docket No. IC09–715–001]
address upon receipt of comments.
For paper filings, an original and 2
Commission Information Collection
copies of the comments should be
Activities (FERC–715); Comment
submitted to the Federal Energy
Request; Submitted for OMB Review
Regulatory Commission, Secretary of the
Commission, 888 First Street, NE.,
November 23, 2009.
Washington, DC 20426, and should refer
AGENCY: Federal Energy Regulatory
to Docket No. IC09–715–001.
Commission.
All comments may be viewed, printed
ACTION: Notice.
or downloaded remotely via the Internet
through FERC’s homepage using the
SUMMARY: In compliance with the
‘‘eLibrary’’ link. For user assistance,
requirements of section 3507 of the
contact [email protected] or
Paperwork Reduction Act of 1995, 44
toll-free at (866) 208–3676 or for TTY,
U.S.C. 3507, the Federal Energy
Regulatory Commission (Commission or contact (202) 502–8659.
FERC) has submitted the information
FOR FURTHER INFORMATION CONTACT:
collection described below to the Office Ellen Brown may be reached by
of Management and Budget (OMB) for
telephone at (202) 502–8663, by fax at
review of the information collection
(202) 273–0873, and by e-mail at
requirements. Any interested person
[email protected].
may file comments directly with OMB
SUPPLEMENTARY INFORMATION: The
and should address a copy of those
FERC–715 (‘‘Annual Transmission
comments to the Commission as
Planning and Evaluation Report,’’ OMB
explained below. The Commission
Control No. 1902–0171) is a mandatory
received one comment in response to
filing described at 18 CFR 141.300. The
the Federal Register notice (74FR47566, FERC–715 must be submitted by each
9/16/2009). FERC has summarized and
transmitting utility that operates
addressed the commenter’s suggestions
integrated (that is, non-radial)
below and in its submission to OMB.
transmission facilities at or above 100
DATES: Comments on the collection of
kilovolts. [An overview and current
information are due by January 4, 2010.
instructions for filing the FERC–715 are
ADDRESSES: Address comments on the
posted on the FERC Web site at:
collection of information to the Office of http://www.ferc.gov/docs-filing/eforms/
Management and Budget, Office of
form-715/instructions.asp.]
Section 213 (b) of the Federal Power
Information and Regulatory Affairs,
Act (FPA), as amended by the Energy
Attention: Federal Energy Regulatory
Commission Desk Officer. Comments to Policy Act of 1992, requires FERC to
collect, annually from transmitting
OMB should be filed electronically, c/o
utilities, sufficient information about
[email protected] and
their transmission systems to inform
include OMB Control Number 1902–
potential transmission customers, state
0171 as a point of reference. The Desk
regulatory authorities, and the public, of
Officer may be reached by telephone at
202–395–4638. A copy of the comments available transmission capacity and
constraints. FERC–715 also supports the
should also be sent to the Federal
Commission’s expanded responsibilities
Energy Regulatory Commission and
under Sections 211, 212, 213(a), 304,
should refer to Docket No. IC09–715–
307(a), 309, and 311 of the FPA, as
001. Comments may be filed either

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amended, for reviewing reliability
issues, market structure relationships,
and in rate and other regulatory
proceedings.
A summary of the comment filed,
FERC’s response, and proposed changes
to the requirements follow.
a. Comment: FERC Order No. 890 now
requires regional transmission planning
processes. We suggest that respondents
be allowed to refer to Attachment K
information already available on
Regional Planning Web sites.
FERC response: Respondents are
already encouraged to incorporate
references to readily available
information when preparing their
FERC–715 submissions. External
information is most often used in Part
IV, Transmission Planning Reliability
Criteria. However, Order No. 890 does
not require utilities to file power flow
data or maps with the Commission or
otherwise make this data available.
Therefore, FERC–715 is the only source
for these items.
b. Comment: The commenter suggests
FERC should allow filing via the
Internet, as well as on CDs, DVDs,
diskettes, or in hard copy.
FERC response: The Commission
agrees that Internet filing has the
potential to reduce the burden to
industry. Respondents are already given
the option of filing via the Internet
(through eFiling), if the submission can
be completed using acceptable file
formats. Filings may also be made on
CD or DVD. The option of using
diskettes is being eliminated, however,
due to advances in technology and file
sizes being too large for the medium.
c. Comment: The commenter suggests
that a list of changes be provided when
the FERC–715 instructions are updated.
FERC response: FERC agrees and will
provide this information to respondents
beginning with the 2010 filing.
d. Comment: Certain parts of FERC–
715 need only be updated when
information changes from previous
filings. The commenter suggests that
respondents be required to report the
last filing date of information that is
unchanged.
FERC response: FERC agrees and will
incorporate this requirement into the
FERC–715 instructions. To reduce the
burden on industry, if this date is prior
to the 2010 filing deadline, Respondents
need only state that the previous filing
was ‘‘prior to the 2010 filing.’’
e. Comment: FERC–715 responses are
considered Critical Energy
Infrastructure Information (CEII), and
parties requesting access to this data
must be vetted and approved by FERC.
These parties may also request CEII
directly from FERC–715 respondents.

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We suggest that FERC attempt to
confirm to Respondents that parties
requesting access to this data have
passed the necessary background
checks.
FERC response: The process for
requesting CEII from the Commission is
detailed in Order Nos. 702, 683, 662,
649, 643, 630, and PL02–01–000, and on
http://www.ferc.gov. FERC–715 is not an
appropriate venue to address the CEII

request process, but the FERC offices
responsible for handling CEII requests
have been made aware of the suggestion.
A copy of the proposed, revised
instructions is attached and part of this
document, but the instructions are not
being printed in the Federal Register.
The Attachment is available on the
FERC’s eLibrary (http://www.ferc.gov/
docs-filing/elibrary.asp) by searching
Number of
respondents
annually
(1)

FERC data collection

FERC–715 .......................................................................................................

Docket No. IC09–715–001, and through
the FERC Public Reference Room.
Action: The Commission is requesting
a three-year extension of the current
expiration date for the FERC–715, with
the changes noted above and in the
attached draft instructions.
Burden Statement: Public reporting
burden for this collection is estimated as
follows.
Number of
responses per
respondent
(2)

120

1

Average
burden hours
per response
(3)
160

Total annual
burden hours
(1) × (2) × (3)
19,200

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[Note: These figures may not be exact, due to rounding.]

The total estimated annual cost
burden 1 to respondents is $1,184,279.90
[(19,200 hrs.)/(2,080 hrs./yr.)] ×
($128,297 per yr.).
The reporting burden includes the
total time, effort, or financial resources
expended to generate, maintain, retain,
disclose, or provide the information
including: (1) Reviewing instructions;
(2) developing, acquiring, installing, and
utilizing technology and systems for the
purposes of collecting, validating,
verifying, processing, maintaining,
disclosing and providing information;
(3) adjusting the existing ways to
comply with any previously applicable
instructions and requirements; (4)
training personnel to respond to a
collection of information; (5) searching
data sources; (6) completing and
reviewing the collection of information;
and (7) transmitting, or otherwise
disclosing the information.
The estimate of cost for respondents
is based upon salaries for professional
and clerical support, as well as direct
and indirect overhead costs. Direct costs
include all costs directly attributable to
providing this information, such as
administrative costs and the cost for
information technology. Indirect or
overhead costs are costs incurred by an
organization in support of its mission.
These costs apply to activities which
benefit the whole organization rather
than any one particular function or
activity.
Comments are invited on: (1) Whether
the proposed collections of information
are necessary for the proper
performance of the functions of the
Commission, including whether the
information will have practical utility;
(2) the accuracy of the agency’s
estimates of the burden of the proposed
collections of information, including the
1 Employees work an average of 2,080 hours per
year, at an estimated cost of $128,297 per year.

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validity of the methodology and
assumptions used; (3) ways to enhance
the quality, utility and clarity of the
information to be collected; and (4)
ways to minimize the burden of the
collection of information on those who
are to respond, including the use of
appropriate automated, electronic,
mechanical, or other technological
collection techniques or other forms of
information technology, e.g. permitting
electronic submission of responses.
Kimberly D. Bose,
Secretary.
Note: The Attachment (proposed, revised
instructions) will not be printed in the
Federal Register. The Attachment is
available on the FERC’s eLibrary (http://
www.ferc.gov/docs-filing/elibrary.asp) by
searching Docket No. IC09–715–001, and
through the FERC Public Reference Room.
Attachment
FERC–715—Annual Transmission Planning
and Evaluation Report Instructions
Revised November 2009.
Approved OMB Control No. 1902–0171.
Expires: (MM/DD/YY).
This report is mandatory under Sections
213(b), 307(a) and 311 of the Federal Power
Act and 18 CFR Section 141.300 of the
Commission’s regulations.
§ 141.300 FERC Form No. 715, Annual
Transmission Planning and Evaluation
Report
Who must file: Any transmitting utility, as
defined in § 3(23) of the Federal Power Act,
that operates integrated (that is, non-radial)
transmission facilities at or above 100
kilovolts must complete FERC Form No. 715;
When to file: FERC Form No. 715 must be
filed on or before each April 1st;
What to file: FERC Form No. 715 must be
filed with the Office of the Secretary of the
Federal Energy Regulatory Commission in
accordance with the instructions on that
form.
The Commission considers the information
collected by this report to be Critical Energy

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Infrastructure Information (CEII) and will
treat it as such. The public reporting burden
for this collection of information is estimated
to average 160 hours per response, including
the time for reviewing the instructions,
searching existing data sources, gathering
and maintaining the data needed, and
completing and reviewing the collection of
information. You shall not be penalized for
failure to respond to this collection of
information unless the collection of
information displays a valid OMB control
number. Send comments regarding this
burden estimate or any other aspect of this
collection of information, including
suggestions for reducing this burden, to:
Federal Energy Regulatory Commission,
Office of the Deputy Chief Information
Officer, ATTN: Information Clearance
Officer (ED–32), 888 First Street, NE.,
Washington, DC 20426.
and to:
Office of Management and Budget, Office of
Information and Regulatory Affairs. ATTN:
Desk Officer for the Federal Energy
Regulatory Commission, Washington, DC
20503.
Table of Contents
I. General Information
A. Purpose of Report
B. Who Must Submit
C. Waiver Request
D. Blank or N/A (Not Applicable)
Responses
E. Checklist and Where to Submit
F. When to Submit
G. Contact Information
H. Sanctions and Confidentiality
Statements
II. General Instructions
A. Submit
B. Designate Entity to Submit Power Flow
Cases
C. Fee Schedule
D. The Importance of Power Flow Cases in
the Evaluation of System Performance
III. Terms and Definitions
A. Transmission Planning Reliability
Criteria
B. Transmitting Utility
IV. Specific Instructions
A. Part 1: Identification and Certification

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B. Part 2: Power Flow Base Cases
C. Part 3: Transmitting Utility Maps and
Diagrams
D. Part 4: Transmission Planning
Reliability Criteria
E. Part 5: Transmission Planning
Assessment Practices
F. Part 6: Evaluation of Transmission
System Performance

E. Checklist and Where To Submit

I. General Information
A. Purpose of Report
The FERC Form No. 715, Annual
Transmission Planning and Evaluation
Report, is required pursuant to Sections
213(b), 307(a) and 311 of the Federal Power
Act to provide information adequate to
inform potential transmission customers,
State regulatory authorities and the public of
potential transmission capacity and known
constraints, to support the Commission’s
expanded responsibilities under §§ 211, 212
and 213(a) of the Federal Power Act (as
amended by the Energy Policy Act), and to
assist in rate or other regulatory proceedings.
B. Who Must Submit
Each transmitting utility, as defined in
section 3(23) of the Federal Power Act, that
operates network (that is, non-radial)
transmission facilities at or above 100
kilovolts must report the information
requested under the listed items in the
prescribed manner. In the case of joint
ownership, only the operator of the facilities
must report.
A designated agent, such as a regional
transmission group, regional reliability
organization, formal power pool, or other
group, may submit part or all of the required
information on behalf of the transmitting
utility. The transmitting utility is responsible
for submitting all data not submitted on its
behalf by a designated agent. Designated
agents must specify the transmitting utility
(or transmitting utilities) for which they are
submitting information. The Commission
prefers that all power flow data submitted for
Part 2 of FERC–715 be submitted by
designated agents outlined above.

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C. Waiver Request
The final rule requires that an entity
requesting waiver of FERC–715 must either:
(1) Indicate the entity that performs
transmission planning for it, or (2) state that
it does not use power flow analyses in
performing transmission planning. Once
granted, a waiver request in subsequent years
is unnecessary, provided the party’s status
does not change; that is, as long as the party
does not begin to perform transmission
planning or to use power flow analyses in its
planning. Requests for waivers must be
submitted prior to the required submission
date, April 1st of the filing year.
D. Blank or N/A (Not Applicable) Responses
All parts of the FERC–715 must be
completed. Blank or N/A (Not Applicable)
responses are not acceptable. For example;
for Parts 4 and 5, respondent transmitting
utilities should state the reasons why they
have not developed specific transmission
reliability criteria or assessment practices for
their own system in addition to that of the
regional entities if that should be the case.

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Respondents may send their responses via
FERC eFiling, if all the files comprising the
submission are on the list of FERC acceptable
file formats.
Respondents who are unable or unwilling
to use the FERC eFiling system must submit
one original, either in hardcopy or
electronically on CDs or DVDs, including all
six Parts of FERC–715 to: Federal Energy
Regulatory Commission, Form No. 715,
Secretary of the Commission, 888 First Street,
NE., Washington, DC 20426.
F. When To Submit
File the report annually by April 1st of the
filing year.
G. Contact Information
Direct technical questions concerning the
FERC–715, Annual Transmission Planning
and Evaluation Report, to email
[email protected].
H. Sanctions and Confidentiality Statements
The FERC–715, Annual Transmission
Planning and Evaluation Report, is
mandatory under the Federal Power Act. The
information reported in FERC–715 is
classified as CEII. Late filing or failure to file,
keep records, or comply with these
instructions may result in criminal fines,
civil penalties, and other sanctions as
provided by law.
II. General Instructions
The Federal Energy Regulatory
Commission (Commission) has determined
that to satisfy section 213(b) of the Federal
Power Act (FPA) it is necessary for potential
customers to be able to reasonably anticipate
the outcome of technical studies that a
transmitting utility would perform in
assessing the availability of transmission
capacity to satisfy a request for transmission
service. Therefore, the Commission requires
each transmitting utility, or its designated
agent, to:
A. Submit
The Commission requires each
transmitting utility, or its designated agent, to
submit an annual report that includes:
1. Power flow base cases for its
transmission system, or if the transmitting
utility belongs to a regional or subregional
transmission planning or reliability
organization, power flow base cases for that
region or subregion;
2. System maps and one-line diagrams;
3. A description of their reliability criteria
and transmission planning assessment
practices; and
4. An evaluation under the reliability
criteria of the current and future performance
of their transmission system.
B. Designate Entity To Submit Power Flow
Cases
The Commission requires each
transmitting utility, or its agent, to designate
any regional or subregional transmission
planning or reliability organizations to which
it belongs or any other single entity to submit
to the Commission any regional or
subregional power flow base cases developed

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for the purposes of members’ transmission
planning.
C. Fee Schedule
If Respondents make CEII directly available
to the requesting public and desire to impose
copying charges for this service, they shall
provide a fee schedule.
D. The Importance of Power Flow Cases in
the Evaluation of System Performance
The Commission assumes that most
transmitting utilities participate in the
development, by a regional or subregional
organization to which they belong, of
regional or subregional power flow base
cases. The purpose of this process is to
ensure consistency of assumptions and
accuracy of data.
Individual members of regional or
subregional organizations use these power
flow cases as the starting place for their own
transmission planning studies. A detailed
description of a transmitting utility’s
reliability criteria and planning practices and
an evaluation of system performance are
essential to perform planning studies, to
assess the availability of transmission, to
identify potential constraints, and to
anticipate the outcome of transmitting utility
technical studies made in response to an
actual request for service.
III. Terms and Definitions
A. Transmission Planning Reliability Criteria
The measuring systems and performance
standards that are used for assessing the
actual or projected ability of the bulk electric
transmission system to deliver power to load
reliably. Failure to attain a specified
performance standard indicates the need to
consider adding or rearranging facilities,
changing operating modes, or other
responses.
Examples of criteria that might apply to
simulated testing of the bulk electric
transmission system are:
1. No cascading outage following any
specified set of contingencies.
2. No overloaded facilities following a
specified contingency.
3. All voltages within prescribed limits.
B. Transmitting Utility
Any electric utility, qualifying
cogeneration facility (section 3(18)(B), FPA),
qualifying small power production facility
(section 3(17)(C), FPA), or Federal power
marketing agency (section 3(19), FPA) that
owns or operates electric power transmission
facilities that are used for the sale of electric
energy at wholesale. (section 3(23), FPA)
IV. Specific Instructions
A. Part 1: Identification and Certification
Provide the following information:
1. Transmitting Utility Name
2. Transmitting Utility Mailing Address
3. Contact Person Name
4. Contact Person Title
5. Contact Person Telephone Number
6. Contact Person Facsimile Number
7. Certification by an authorized official of
the Transmitting Utility regarding the
accuracy of the information submitted.
8. Certifying Official Signature

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9. Certifying Official Name
10. Certifying Official Title
B. Part 2: Power Flow Base Cases
A Respondent participating in a regional or
subregional process (for consolidating and
ensuring the consistency and accuracy of the
power flow information used by the
Respondent for transmission planning) must
submit the most current regional or
subregional input data to solved power flow
base cases that the transmitting utility would
ordinarily use as the starting point for its
transmission planning studies or, where
these data are unavailable from a regional
organization, submit such data itself.
If the Respondent participates in such a
regional or subregional process, it must
submit the following items:
1. Regional or subregional organization
name;
2. Regional or subregional organization
mailing address;
3. Regional or subregional organization
contact person;
4. Regional or subregional organization
contact person title;
5. Regional or subregional organization
contact person telephone number;
6. Regional or subregional organization
contact person facsimile number;
7. Description of process for public access
to regional or subregional power flow
information; and
8. Description of power flow cases
currently available from regional or
subregional organization, including time
frame, conditions, format, media and the
fees, if any, for copying data for the public.
If a Respondent does not participate in the
development of regional or subregional
transmission planning power flow base cases,
the Respondent must submit its own
equivalent power flow base cases directly to
the Commission.
Each Respondent must submit for each
solved power flow base case: the input data
file (in formats described below) and the
corresponding output data file (in ASCII
format) showing the solved real and reactive
power flows, voltages, real and reactive
generation and loads, solution parameters,
and other relevant output information; or, in
the alternative, at a minimum, a one-line
diagram showing real and reactive power
flows, bus voltages and angles, generator
outputs, transformer tap settings and loads.
Regional and subregional organizations
authorized by their members to provide
access to solved power flow cases should
make them available electronically on CDs or
DVDs, or via a computer bulletin board,
when practical, in the input data format
associated with the power flow program that
the regional or subregional organizations use
in their transmission studies. The
Commission expects that, in nearly all cases,
the format will be one of the following:
1. The Raw Data File format of the PTI
(Power Technologies, Inc.) PSS/E Power flow
program;
2. The Card Deck Image format of the
Philadelphia Electric Power flow program;
3. The Card Deck format of the WSCC
Power flow program;
4. The Raw Data File format of the General
Electric PSLF power flow program;

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5. The IEEE Common Format for Exchange
of Solved Power Flows; or
6. The Binary or Project File format of the
PowerWorld simulator.
Respondents submitting their own cases
must supply the input data to the solved base
cases and associated ASCII output data on
CDs or DVDs in the format associated with
the power flow program used by the
Respondents in the course of their
transmission studies, as described above.
The power flow cases may also be
submitted via eFiling, if they are available in
an acceptable file format. A list of acceptable
file formats is available on the FERC eFiling
website.
The input data to the solved power flow
base cases must be forward-looking. For
example, the power flow base cases
submitted and made available might include:
1. One, two, five and ten-year forecasts
under summer and winter peak conditions
and
2. A one-year forecast under light load/
heavy transfers condition.
This example is similar to a schedule of
base cases proposed by North American
Electric Reliability Corporation’s (NERC)
Multiregional Modeling Working Group for
development at the time this form was
created. A regional or subregional
organization may develop, depending on its
needs, a different number of power flow base
cases than those described above.
The power flow base cases must be in
sufficient detail that network equivalents, if
used, extend sufficiently beyond the
electrical borders of the transmitting utility
that potential transmission users could
simulate power transfers within a reasonable
market area without significant loss of
accuracy.
The power flow base cases should include
all branch circuit ratings (that is, normal,
long-term and short-term emergency, or other
relevant ratings) that a Respondent uses.
Each Respondent must also submit or make
available a data-dictionary that crossreferences the bus or line terminal names.
Energy Information Administration (EIA)
codes must be included for each generating
plant referenced. | EIA Plant Codes
C. Part 3: Transmitting Utility Maps and
Diagrams
1. Each Respondent must submit general
transmission maps and single-line schematic
diagrams. The maps and diagrams should be
those prepared in the general course of
business for planning and operating
purposes. The guidelines provided below
indicate the type of information and the level
of detail desired; however, the Commission
is not requiring the Respondent to
specifically prepare new maps and diagrams
to satisfy this requirement. If the Respondent
has readily available more than one set of
maps and/or diagrams, the Commission
requests that the set submitted best provide
the level of detail described below.
2. The transmitting utility’s general maps
should show the geographic locations and
names of:
a. Generating plants;
b. Switching stations;
c. Substations;

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d. Service areas; and
e. Interconnections with other utilities.
3. The transmitting utility’s single-line
schematic diagrams should show and
identify:
a. AC and DC transmission lines and
facilities, including their nominal operating
and design voltages;
b. Electrical connections;
c. Generating plants;
d. Transformation facilities;
e. Phase angle transformers; and
f. VAR control equipment; (i.e., shunt and
series capacitors and inductors, etc.).
4. On the maps or in separate
documentation, each Respondent should
provide a legend that shows the symbols
used on the map or diagram to represent
generators, transmission lines, transformers,
capacitors, reactors, buses, etc.
5. Respondents must submit new maps or
diagrams each year regardless of its revision.
6. The FERC prefers all maps and diagrams
be submitted electronically in a format such
that any text is searchable. For example,
these maps typically list many substations,
and FERC prefers that the format support a
search for specific substation names. The
Adobe PDF format is an example of a
common file type that provides this feature.
D. Part 4: Transmission Planning Reliability
Criteria
Each Respondent is to provide the
transmission planning reliability criteria
used to assess and test the strength and limits
of its transmission system to meet its load
responsibility as well as to move bulk power
between and among other electric systems.
If a transmitting utility subscribes, through
its interconnection or pooling agreements
with others, to criteria that are more detailed
than the NERC and regional entity standards,
then it must also submit these additional
criteria.
The Commission expects that each
transmitting utility will have additional
detailed criteria. For example, each utility
generally sets its own voltage limit criteria on
its bulk system as well as its lower voltage
system, since NERC and the regional entities
generally do not. Each transmitting utility
must submit all such additional criteria.
The above criteria will be those which the
transmitting utility uses to determine
available transmission capacity needed to
meet potential transmission requests as well
as its own native load. A transmitting utility
must describe the criteria that it uses in
sufficient detail to allow others to use the
criteria when performing their own planning
or screening studies and to better understand
the process of determining available
transmission capacity.
In subsequent years, Respondents need
only identify and file changed criteria. If the
criteria are unchanged from a previous filing,
please provide the date of that filing. If this
date is prior to the 2010 filing deadline,
Respondents need only state that the
previous filing was ‘‘prior to the 2010 filing.’’
E. Part 5: Transmission Planning Assessment
Practices
The criteria submitted under Part 4 of this
form set the limits of transmission use.

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Federal Register / Vol. 74, No. 230 / Wednesday, December 2, 2009 / Notices

mstockstill on DSKH9S0YB1PROD with NOTICES

However, assessment practices that a
transmitting utility uses in applying these
criteria are as important as the criteria
themselves. These practices, developed
through experience and study, include
consideration of detailed factors that a
transmitting utility may not list in the criteria
that it submits under Part 4. For example, a
utility might have certain operating
restrictions and limitations that must be met
by appropriate modeling within a simulation
study.
Also, through experience and study, each
transmitting utility may have developed a list
of various contingencies it typically tests
against in the application of its transmission
planning reliability criteria. For example,
before testing for the limits of transmission
capability that could be used for firm power
transfers on its system, a transmitting utility
will assume, based on experience or realistic
expectation, that certain facilities will be
unavailable for some period of time. Each
transmitting utility must identify these
contingencies and submit them under this
Part.
A description of the Respondent’s practices
when applying the transmission planning
reliability criteria submitted in Part 4 must be
submitted under this part. The description
must include the substantive planning
assessment practices that a Respondent
follows in the normal course of business. The
information filed should help requesters to
perform planning or screening studies and to
better understand the process of determining
available transmission capacity and known
constraints.
In subsequent years, Respondents need
only identify and file changed assessment
practices. If the practices are unchanged from
a previous filing, please provide the date of
that filing. If this date is prior to the 2010
filing deadline, Respondents need only state
that the previous filing was ‘‘prior to the
2010 filing.’’
F. Part 6: Evaluation of Transmission System
Performance
The transmitting utility must provide a
narrative evaluation or assessment of the
performance of its transmission system in
future time periods based on the application
of its reliability criteria. It must provide a
clear understanding of existing and likely
future transmission constraints, their sources,
how it identified these constraints, and a
description of any plans to mitigate the
constraints. The evaluation must provide a
clear understanding of the existing and
expected system performance of the
Respondent’s transmission system. The
evaluation should include a description of all
existing transmission stability limits that the
transmitting utility has uncovered through
dynamic system simulation studies. If, in
their studies, Respondents identify stability
as a regional transmission limiting factor,
Respondents must, on request, provide the
results of their studies.
The required evaluation is to be drawn
from existing utility transmission planning
studies and the experience and judgment of
the Respondents’ transmission system
planners. Respondents may base the required
evaluation, in part, on recently performed

VerDate Nov<24>2008

18:28 Dec 01, 2009

Jkt 220001

operating studies that determine transfer
capabilities for the upcoming peak load
season.
[FR Doc. E9–28791 Filed 12–1–09; 8:45 am]
BILLING CODE 6717–01–P

DEPARTMENT OF ENERGY
Federal Energy Regulatory
Commission
[ P–13590–000]

Lockhart Power Company; Notice of
Intent To File License Application,
Filing of Pre-Application Document,
and Approving Use of the Traditional
Licensing Process
November 23, 2009.

a. Type of Filing: Notice of Intent to
File License Application and Request to
Use the Traditional Licensing Process.
b. Project No.: 13590–000.
c. Date Filed: September 28, 2009.
d. Submitted By: Lockhart Power
Company (Lockhart Power).
e. Name of Project: Riverdale
Hydroelectric Project.
f. Location: On the Enoree River in
Spartanburg and Laurens Counties,
South Carolina. No federal lands are
occupied by the project works or located
within the project boundary.
g. Filed Pursuant to: 18 CFR 5.3 of the
Commission’s Regulations
h. Potential Applicant Contact: Bryan
Stone, Lockhart Power Company, Chief
Operating Officer, 420 River Street, P.O.
Box 10, Lockhart, South Carolina 29364;
1–800–368–1289.
i. FERC Contact: Bryan RodenReynolds at (202) 502–6618; or e-mail at
[email protected].
j. Lockhart Power filed its request to
use the Traditional Licensing Process on
September 28, 2009. Lockhart Power
provided public notice of its request on
September 29 and 30, 2009. In a letter
dated November 20, 2009, the Director
of the Office of Energy Projects
approved Lockhart Power’s request to
use the Traditional Licensing Process.
k. With this notice, we are initiating
informal consultation with: (a) The U.S.
Fish and Wildlife Service and National
Marine Fisheries Service (NMFS) under
section 7 of the Endangered Species Act
and the joint agency regulations
thereunder at 50 CFR part 402; (b)
NMFS under section 305(b) of the
Magnuson-Stevens Fishery
Conservation and Management Act and
implementing regulations at 50 CFR
600.920; and (c) the South Carolina
State Historic Preservation Officer, as
required by Section 106, National
Historical Preservation Act, and the
implementing regulations of the

PO 00000

Frm 00031

Fmt 4703

Sfmt 4703

Advisory Council on Historic
Preservation at 36 CFR 800.2.
l. With this notice, we are designating
Lockhart Power as the Commission’s
non-federal representative for carrying
out informal consultation, pursuant to
Section 7 of the Endangered Species
Act, Section 305 of the MagnusonStevens Fishery Conservation and
Management Act, and Section 106 of the
National Historic Preservation Act.
m. Lockhart Power filed a PreApplication Document (PAD; including
a proposed process plan and schedule)
with the Commission, pursuant to 18
CFR 5.6 of the Commission’s
regulations.
n. A copy of the PAD is available for
review at the Commission in the Public
Reference Room or may be viewed on
the Commission’s Web site (http://
www.ferc.gov), using the ‘‘eLibrary’’
link. Enter the docket number,
excluding the last three digits, in the
docket number field to access the
document. For assistance, contact FERC
Online Support at
[email protected], or toll
free at 1–866–208–3676, or for TTY,
(202) 502–8659. A copy is also available
for inspection and reproduction at the
address in paragraph h.
o. Register online at http://
www.ferc.gov/docs-filing/
esubscription.asp to be notified via email of new filings and issuances
related to this or other pending projects.
For assistance, contact FERC Online
Support.
Kimberly D. Bose,
Secretary.
[FR Doc. E9–28793 Filed 12–1–09; 8:45 am]
BILLING CODE 6717–01–P

DEPARTMENT OF ENERGY
Federal Energy Regulatory
Commission
[Docket No. EL05–146–010]

Independent Energy Producers
Association v. California Independent
System Operator Corporation; Notice
of Compliance Filing
November 24, 2009.

Take notice that on November 20,
2009, Mirant Energy Trading, LLC filed
an amendment to their compliance
refund report submitted on October 2,
2009, pursuant to the Commission’s
order issued on August 18, 2009, 128
FERC ¶ 61,165 (2009) (Order on
Remand).
Any person desiring to intervene or to
protest this filing must file in
accordance with Rules 211 and 214 of

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