Annual Transmission Planning and Evaluation Report

We now accept Form 715 submissions via FERC eFiling.
Revised January 2010
Approved OMB Control No. 1902-0171
Expires: 01/31/2013
This report is mandatory under Sections 213(b), 307(a) and 311 of the Federal Power Act and 18 CFR §
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. In 2012, April 1st is a
Sunday. Form No. 715 will be due on or before Monday, April 2nd.
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 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, N.E.
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.
B.
C.
D.
E.
F.

I.

Part 1:
Part 2:
Part 3:
Part 4:
Part 5:
Part 6:

Identification and Certification
Power Flow Base Cases
Transmitting Utility Maps and Diagrams
Transmission Planning Reliability Criteria
Transmission Planning Assessment Practices
Evaluation of Transmission System Performance

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.
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.
E. Checklist and Where to Submit
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, N.E.
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
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
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. Formats that combine the input and output data in a single file, such as the
PTI SAV format, are also acceptable. Such formats should allow users to access the output data
without having to solve the case.
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 secure
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 or Saved Case formats 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;
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 solved base cases and associated 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 cross-references 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;
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. 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 operating studies that determine
transfer capabilities for the upcoming peak load season.