[Federal Register Volume 86, Number 78 (Monday, April 26, 2021)]
[Notices]
[Pages 22043-22044]
[FR Doc No: 2021-08609]

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DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

Combined Notice of Filings #1

    Take notice that the Commission received the following electric
corporate filings:

    Docket Numbers: EC21-80-000.
    Applicants: Knighthead Capital Management, LLC, Homer City
Generation, L.P.
    Description: Application for Authorization Under Section 203 of the
Federal Power Act of Homer City Generation, L.P., et al.
    Filed Date: 4/20/21.
    Accession Number: 20210420-5059.
    Comments Due: 5 p.m. ET 5/11/21.

    Docket Numbers: EC21-81-000.
    Applicants: Coram California Development, L.P.
    Description: Application for Authorization Under Section 203 of the
Federal Power Act of Coram California Development, L.P.
    Filed Date: 4/19/21.
    Accession Number: 20210419-5320.
    Comments Due: 5 p.m. ET 5/10/21.

    Take notice that the Commission received the following exempt
wholesale generator filings:

    Docket Numbers: EG21-128-000.
    Applicants: Triple Butte LLC.
    Description: Self-Certification of Exempt Wholesale Generator of
Triple Butte LLC.
    Filed Date: 4/19/21.
    Accession Number: 20210419-5212.
    Comments Due: 5 p.m. ET 5/10/21.

    Take notice that the Commission received the following electric
rate filings:

    Docket Numbers: ER21-1276-001.
    Applicants: Midcontinent Independent System Operator, Inc.,
American Transmission Company LLC.
    Description: Tariff Amendment: 2021-04-20_SA 2793 ATC-City of Eagle
River Substitute 1st Rev CFA to be effective 5/5/2021.
    Filed Date: 4/20/21.
    Accession Number: 20210420-5021.
    Comments Due: 5 p.m. ET 5/11/21.

    Docket Numbers: ER21-1277-001.
    Applicants: Midcontinent Independent System Operator, Inc.,
American Transmission Company LLC.
    Description: Tariff Amendment: 2021-04-20_SA 2794 ATC-City of
Gladstone Substitute 1st Rev CFA to be effective 5/5/2021.
    Filed Date: 4/20/21.
    Accession Number: 20210420-5031.
    Comments Due: 5 p.m. ET 5/11/21.

    Docket Numbers: ER21-1713-000.
    Applicants: Midcontinent Independent System Operator, Inc.
    Description: Sec.  205(d) Rate Filing: 2021-04-19_Attachment X,
App. 1 Interconnection Request Requirement Changes to be effective 6/
19/2021.
    Filed Date: 4/19/21.
    Accession Number: 20210419-5171.
    Comments Due: 5 p.m. ET 5/10/21.

    Docket Numbers: ER21-1714-000.
    Applicants: PJM Interconnection, L.L.C.
    Description: Tariff Cancellation: Notice of Cancellation ISA,
Service Agreement No. 5557; Queue No. AE2-057 to be effective 5/21/
2021.
    Filed Date: 4/20/21.
    Accession Number: 20210420-5018.
    Comments Due: 5 p.m. ET 5/11/21.

    Docket Numbers: ER21-1715-000.
    Applicants: PJM Interconnection, L.L.C.
    Description: Sec.  205(d) Rate Filing: Amendment to Service
Agreement No. 5548; Queue No. AC1-076/AE2-134 to be effective 12/16/
2019.
    Filed Date: 4/20/21.
    Accession Number: 20210420-5032.
    Comments Due: 5 p.m. ET 5/11/21.

    Docket Numbers: ER21-1716-000.
    Applicants: BP Energy Retail LLC.
    Description: Baseline eTariff Filing: Application for Market-Based
Rate Authority to be effective 6/20/2021.
    Filed Date: 4/20/21.
    Accession Number: 20210420-5039.
    Comments Due: 5 p.m. ET 5/11/21.

    Docket Numbers: ER21-1717-000.
    Applicants: Duke Energy Florida, LLC.
    Description: Sec.  205(d) Rate Filing: DEF--Annual Update of Real
Power Loss Factors (2021) to be effective 5/1/2021.
    Filed Date: 4/20/21.
    Accession Number: 20210420-5055.
    Comments Due: 5 p.m. ET 5/11/21.

    Docket Numbers: ER21-1718-000.
    Applicants: Idaho Power Company.
    Description: Sec.  205(d) Rate Filing: Goshen Substation Upgrades
to be effective 3/9/2021.
    Filed Date: 4/20/21.
    Accession Number: 20210420-5058.
    Comments Due: 5 p.m. ET 5/11/21.

    Take notice that the Commission received the following PURPA
210(m)(3) filings:

    Docket Numbers: QM21-19-000.
    Applicants: Otter Tail Power Company.
    Description: Application of Otter Tail Power Company to Terminate
Its Mandatory Purchase Obligation under the Public Utility Regulatory
Policies Act of 1978.
    Filed Date: 4/19/21.
    Accession Number: 20210419-5216.
    Comments Due: 5 p.m. ET 5/17/21.

    The filings are accessible in the Commission's eLibrary system
(https://elibrary.ferc.gov/idmws/search/fercgensearch.asp) by querying
the docket number.
    Any person desiring to intervene or protest in any of the above
proceedings must file in accordance with Rules 211 and 214 of the
Commission's Regulations (18 CFR 385.211 and 385.214) on or before 5:00
p.m. Eastern time on the specified comment date. Protests may be
considered, but intervention is necessary to become a party to the
proceeding.
    eFiling is encouraged. More detailed information relating to filing
requirements, interventions, protests, service, and qualifying
facilities filings can be found at: http://www.ferc.gov/docs-filing/efiling/filing-req.pdf. For other information, call<PHONE_NUMBER>
(toll free). For TTY, call<PHONE_NUMBER>.

    Dated: April 20, 2021.
Kimberly D. Bose,
Secretary.
[FR Doc. 2021-08609 Filed 4-23-21; 8:45 am]
BILLING CODE 6717-01-P


[Federal Register Volume 78, Number 12 (Thursday, January 17, 2013)]
[Notices]
[Pages 3924-3925]
[FR Doc No: 2013-00868]

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SECURITIES AND EXCHANGE COMMISSION

[Release No. 34-68625; File No. SR-BX-2013-003]

Self-Regulatory Organizations; NASDAQ OMX BX, Inc.; Notice of
Filing and Immediate Effectiveness of Proposed Rule Change To Reduce
Fees Assessed for Certain Co-Location Services

January 11, 2013.
    Pursuant to Section 19(b)(1) of the Securities Exchange Act of 1934
(``Act''),\1\ and Rule 19b-4 thereunder,\2\ notice is hereby given that
on January 2, 2013, NASDAQ OMX BX, Inc. (``BX'' or ``Exchange'') filed
with the Securities and Exchange Commission (``Commission'') a proposed
rule change as described in Items I, II, and III below, which Items
have been prepared by the Exchange. The Commission is publishing this
notice to solicit comments on the proposed rule change from interested
persons.
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    \1\ 15 U.S.C. 78s(b)(1).
    \2\ 17 CFR 240.19b-4.
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I. Self-Regulatory Organization's Statement of the Terms of the
Substance of the Proposed Rule Change

    BX proposes to reduce the fees assessed under BX Rule 7034 for
certain co-location services. The Exchange is proposing to implement
the proposed fee beginning on January 2, 2013. The text of the proposed
rule change is available at http://nasdaqomxbx.cchwallstreet.com, at
BX's principal office, and at the Commission's Public Reference Room.

II. Self-Regulatory Organization's Statement of the Purpose of, and
Statutory Basis for, the Proposed Rule Change

    In its filing with the Commission, the self-regulatory organization
included statements concerning the purpose of, and basis for, the
proposed rule change and discussed any comments it received on the
proposed rule change. The text of those statements may be examined at
the places specified in Item III [sic] below. The Exchange has prepared
summaries, set forth in sections A, B, and C below, of the most
significant parts of such statements.

A. Self-Regulatory Organization's Statement of the Purpose of, and
Statutory Basis for, the Proposed Rule Change

1. Purpose
    The Exchange proposes to amend BX Rule 7034 to reduce the monthly
recurring cabinet (``MRC'') fees assessed for the installation of
certain new co-location cabinets. The reduced MRC fees will apply to
new cabinets ordered by customers using the CoLo Console \3\ during the
months of January and February of 2013, provided that such cabinets are
fully operational by May 31, 2013. The reduced fee shall apply to any
cabinet that increases the number of dedicated cabinets beyond the
total number dedicated to that customer as of December 31, 2012
(``Baseline Number''), for so long as the total number of dedicated
cabinets exceeds that customer's Baseline Number. The reduced MRC fees
will apply for a period of 24 months from the date the new cabinet
becomes fully operational under BX rules, provided that the customer's
total number of cabinets continues to exceed the Baseline Number.
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    \3\ The ``CoLo Console'' is BX's web-based ordering tool, and it
is the exclusive means for ordering colocation services.
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    The Exchange proposes to reduce the applicable fees as follows:

------------------------------------------------------------------------
                                              Current         Reduced
              Cabinet type                    ongoing         ongoing
                                            monthly fee     monthly fee
------------------------------------------------------------------------
Low Density.............................          $4,000          $2,000
Medium Density..........................           5,000           2,500
Medium-High Density.....................           6,000           3,500
High Density............................           7,000           4,500
Super High Density......................          13,000           8,000
------------------------------------------------------------------------

    New cabinets shall be assessed standard installation fees.
    BX proposes to reduce colocation cabinet fees by different amounts
to maintain a sliding scale of lower fees for higher density cabinets
on a per kilowatt basis. The chart below reflects this scale:

----------------------------------------------------------------------------------------------------------------
                                                                    Reduced MRC
                  Cabinet type                        Max kW            fee        Discount  (%)    Fee per KW
----------------------------------------------------------------------------------------------------------------
Low Density.....................................            2.88          $2,000           50.00         $694.44
Medium Density..................................            5              2,500           50.00          500.00
Medium-High Density.............................            7              3,500           41.67          500.00
High Density....................................           10              4,500           35.71          450.00
Super High Density..............................           17              8,000           38.46          470.59
----------------------------------------------------------------------------------------------------------------

2. Statutory Basis
    The Exchange believes that the proposed rule change is consistent
with the provisions of Section 6 of the Act,\4\ in general, and with
Section 6(b)(4) of the Act,\5\ in particular, in that it provides for
the equitable allocation of reasonable dues, fees and other charges
among members and issuers and other persons using any facility or
system which the Exchange operates or controls. The proposed reduced
fee will be assessed equally on all customers that place an order for a
new cabinet during the designated period. The proposed amendments will
provide an incentive for customers to avail

themselves of the designated co-location services.
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    \4\ 15 U.S.C. 78f.
    \5\ 15 U.S.C. 78f(b)(4).
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    BX's proposal to reduce fees by differing amounts is fair and
equitable because it reflects the economic efficiency of higher density
colocation cabinets. First, the underlying costs for co-location
cabinets consists [sic] of certain fixed costs for the data center
facility (space, amortization, etc.) and certain variable costs
(electrical power utilized and cooling required). The variable costs
are in total higher for the higher power density cabinets, as reflected
in their higher current prices. Second, the higher density cabinets
were introduced later than the lower density cabinets (High Density
cabinet was introduced in 2009 and the Super High Density cabinet was
introduced in 2011). Due to the competitive pressures that existed in
2011 and 2012, the fees for Super High Density cabinets were further
reduced in 2012 to be more comparable with the lower fee per kilowatt
of the High Density cabinet. As a result of these already-reduced rates
on higher density cabinets, BX has greater flexibility to discount fees
for lower density cabinets, on a per kilowatt basis.
    BX operates in a highly competitive market in which market
participants can readily favor competing venues if they deem fee levels
at a particular venue to be excessive. In such an environment, BX must
continually adjust its fees to remain competitive with other exchanges
and with alternative trading systems that have been exempted from
compliance with the statutory standards applicable to exchanges. BX
believes that the proposed rule change reflects this competitive
environment because it is designed to ensure that the charges for use
of the BX colocation facility remain competitive.

B. Self-Regulatory Organization's Statement on Burden on Competition

    The Exchange does not believe that the proposed rule change will
result in any burden on competition that is not necessary or
appropriate in furtherance of the purposes of the Act, as amended. To
the contrary, the Exchange's voluntary fee reduction is a response to
increased competition for colocation services by other exchanges and
trading venues. As more venues offer colocation services, competition
drives costs lower. The Exchange, in order to retain existing orders
and to attract new orders, is forced to offer a lower effective rate
for aggregate cabinet demand. This competition benefits users, members.
and investors by lowering the average aggregate cost of trading on the
Exchange.

C. Self-Regulatory Organization's Statement on Comments on the Proposed
Rule Change Received From Members, Participants, or Others

    Written comments were neither solicited nor received.

III. Date of Effectiveness of the Proposed Rule Change and Timing for
Commission Action

    Pursuant to Section 19(b)(3)(A)(ii) of the Act,\6\ the Exchange has
designated this proposal as establishing or changing a due, fee, or
other charge imposed by the self-regulatory organization on any person,
whether or not the person is a member of the self-regulatory
organization, which renders the proposed rule change effective upon
filing.
---------------------------------------------------------------------------

    \6\ 15 U.S.C. 78s(b)(3)(A)(ii).
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    At any time within 60 days of the filing of the proposed rule
change, the Commission summarily may temporarily suspend such rule
change if it appears to the Commission that such action is necessary or
appropriate in the public interest, for the protection of investors, or
otherwise in furtherance of the purposes of the Act. If the Commission
takes such action, the Commission shall institute proceedings to
determine whether the proposed rule should be approved or disapproved.

IV. Solicitation of Comments

    Interested persons are invited to submit written data, views, and
arguments concerning the foregoing, including whether the proposed rule
change is consistent with the Act. Comments may be submitted by any of
the following methods:

Electronic Comments

     Use the Commission's Internet comment form (http://www.sec.gov/rules/sro.shtml); or
     Send an email to<EMAIL_ADDRESS>Please include
File Number SR-BX-2013-003 on the subject line.

Paper Comments

     Send paper comments in triplicate to Elizabeth M. Murphy,
Secretary, Securities and Exchange Commission, 100 F Street NE.,
Washington, DC 20549-1090.

All submissions should refer to File Number SR-BX-2013-003. This file
number should be included on the subject line if email is used. To help
the Commission process and review your comments more efficiently,
please use only one method. The Commission will post all comments on
the Commission's Internet Web site (http://www.sec.gov/rules/sro.shtml). Copies of the submission, all subsequent amendments, all
written statements with respect to the proposed rule change that are
filed with the Commission, and all written communications relating to
the proposed rule change between the Commission and any person, other
than those that may be withheld from the public in accordance with the
provisions of 5 U.S.C. 552, will be available for Web site viewing and
printing in the Commission's Public Reference Room on official business
days between the hours of 10:00 a.m. and 3:00 p.m. Copies of such
filing also will be available for inspection and copying at the
principal offices of the Exchange. All comments received will be posted
without change; the Commission does not edit personal identifying
information from submissions. You should submit only information that
you wish to make available publicly. All submissions should refer to
File Number SR-BX-2013-003, and should be submitted on or before
February 7, 2013.

    For the Commission, by the Division of Trading and Markets,
pursuant to delegated authority.\7\
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    \7\ 17 CFR 200.30-3(a)(12).
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Kevin M. O'Neill,
Deputy Secretary.
[FR Doc. 2013-00868 Filed 1-16-13; 8:45 am]
BILLING CODE 8011-01-P


[Federal Register Volume 78, Number 58 (Tuesday, March 26, 2013)]
[Rules and Regulations]
[Pages 18235-18238]
[FR Doc No: 2013-06800]

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DEPARTMENT OF HOMELAND SECURITY

Coast Guard

33 CFR Part 100

[Docket No. USCG-2012-1073]
RIN 1625-AA08

Special Local Regulations; 2013 Lauderdale Air Show, Atlantic
Ocean; Fort Lauderdale, FL

AGENCY: Coast Guard, DHS.

ACTION: Temporary final rule.

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SUMMARY: The Coast Guard is establishing a special local regulation on
the Atlantic Ocean and the entrance of Port Everglades in the vicinity
of Fort Lauderdale, Florida during the 2013 Lauderdale Air Show. The
event is scheduled to take place from Thursday April 18, 2013, until
Sunday, April 21, 2013. The regulation is necessary to ensure the
safety of the participants, spectators, and the general public during
the event. The special local regulation will establish the following
two areas: an exclusion area, where all persons and vessels, except
those persons and vessels participating in the event, are prohibited
from entering, transiting through, anchoring in, or remaining within;
and a limited access area, where all vessels over 500 gross tons will
be prohibited from entering, transiting through, anchoring in, or
remaining within unless authorized by the Captain of the Port Miami or
a designated representative.

DATES: This rule is effective from 10 a.m. on April 18, 2013, until
5:30 p.m. on Sunday, April 21, 2013. The Atlantic Ocean exclusion area
will be enforced daily from 10 a.m. until 5 p.m. from April 18, 2013,
until April 21, 2013. The Port Everglades limited access area will be
enforced daily from 4 p.m. until 5:30 p.m. on April 20, 2013, and April
21, 2013.

ADDRESSES: Documents mentioned in this preamble are part of docket
USCG-2012-1073. To view documents mentioned in this preamble as being
available in the docket, go to http://www.regulations.gov, type the
docket number in the ``SEARCH'' box and click ``SEARCH.'' Click on Open
Docket Folder on the line associated with this rulemaking. You may also
visit the Docket Management Facility in Room W12-140 on the ground
floor of the Department of Transportation West Building, 1200 New
Jersey Avenue SE., Washington, DC 20590, between 9 a.m. and 5 p.m.,
Monday through Friday, except Federal holidays.

FOR FURTHER INFORMATION CONTACT: If you have questions on this rule,
call or email Lieutenant Junior Grade Mike H. Wu, Sector Miami
Prevention Department, Coast Guard; telephone<PHONE_NUMBER>, email
<EMAIL_ADDRESS>If you have questions on viewing or submitting
material to the docket, call Barbara Hairston, Program Manager, Docket
Operations, telephone<PHONE_NUMBER>.

SUPPLEMENTARY INFORMATION:

Table of Acronyms

DHS Department of Homeland Security
FR Federal Register

NPRM Notice of Proposed Rulemaking

A. Discussion of Comments and Changes

    On January 10, 2013, the USCG published a Notice of Proposed
Rulemaking (NPRM) entitled, ``Proposed Rule: NPRM: Special Local
Regulations: 2013 Lauderdale Air Show, Atlantic Ocean; Fort Lauderdale,
FL,'' in the Federal Register (78 FR 2225). We received no comments on
the proposed rule (Docket No. USCG-2012-1073). No public meeting was
requested, and none was held.

B. Basis and Purpose

    From Thursday, April 18, 2013, until Sunday, April 21, 2013,
Lauderdale Air Show, LLC. will be hosting the 2013 Lauderdale Air Show.
The Lauderdale Air Show will include numerous aircraft engaging in
aerobatic maneuvers over the Atlantic Ocean. It is expected that
approximately 500 spectator vessels will be present in the area during
the event. The high speed at which participant aircraft will be
traveling and the maneuvers they will be performing pose a safety
hazard to air show participants, participant aircraft, spectators, and
the general public.
    The legal basis for the rule is the Coast Guard's authority to
establish special local regulations: 33 U.S.C. 1233. The purpose of the
rule is to insure safety of life on navigable waters of the United
States during the 2013 Lauderdale Air Show.

C. Discussion of Comments, Changes and the Final Rule

    The Coast Guard did not receive any comments to the proposed rule
and no changes were made to the regulatory text.
    The Coast Guard is establishing a special local regulation
comprised of two regulated areas for the 2013 Lauderdale Air Show. The
two regulated areas are listed below.
    1. Atlantic Ocean, Fort Lauderdale, Florida (exclusion area).
Certain navigable waters of the Atlantic Ocean in the vicinity of Fort
Lauderdale, Florida. This area will be enforced daily from 10 a.m.
until 5 p.m. from April 18, 2013, through April 21, 2013. All persons
and vessels are prohibited from entering, transiting through, anchoring
in, or remaining within the regulated area unless authorized by the
Captain of the Port Miami or a designated representative.
    2. Port Everglades, Fort Lauderdale, Florida (limited access area).
Certain navigable waters of the Atlantic Ocean in the vicinity of Port
Everglades in Fort Lauderdale, Florida. This will be a limited access
area, and will be enforced daily from 4 p.m. until 5:30 p.m. on April
20, 2013, and April 21, 2013. Vessels over 500 gross tons are
prohibited from entering, transiting through, anchoring in, or
remaining within the regulated area unless authorized by the Captain of
the Port Miami or a designated representative.
    Persons and vessels desiring to enter, transit through, anchor in,
or remain within the regulated area may contact the Captain of the Port
Miami by telephone at<PHONE_NUMBER>, or a designated representative
via VHF radio on channel 16, to request authorization. If authorization
to enter, transit through, anchor in, or remain within the regulated
area is granted by the Captain of the Port Miami or a designated
representative, all persons and vessels receiving such authorization
must comply with the instructions of the Captain of the Port Miami or a
designated representative. The Coast Guard will provide notice of the
special local regulation by Local Notice to Mariners, Broadcast Notice
to Mariners, and on-scene designated representatives.

D. Regulatory Analyses

    We developed this rule after considering numerous statutes and
executive orders related to rulemaking. Below we summarize our analyses
based on these statutes and executive orders.

1. Regulatory Planning and Review

    This rule is not a significant regulatory action under section 3(f)
of Executive Order 12866, Regulatory Planning and Review, as
supplemented by Executive Order 13563, Improving Regulation and
Regulatory Review, and does not require an assessment of potential
costs and benefits under section 6(a)(3) of Executive Order 12866 or
under section 1 of Executive Order 13563. The Office of Management and
Budget has not reviewed it under those orders. The economic impact of
this rule is not significant for the following reasons: (1) The special
local regulation will be enforced for a maximum of 7 and a half hours
each day for only four days; (2) non-participant persons and vessels
may enter, transit through, anchor in, or remain within the exclusion
area during their respective enforcement periods if authorized by the
Captain of the Port Miami or a designated representative; (3) vessels
500 gross tons or more may enter, transit through, anchor in, or remain
within the limited access area during their respective enforcement
periods if authorized by the Captain of the Port Miami or a designated
representative; (4) vessels not able to enter, transit through, anchor
in, or remain within the regulated areas without authorization from the
Captain of the Port Miami or a designated representative may operate in
the surrounding areas during the respective enforcement periods; and
(4) the Coast Guard will provide advance notification of the special
local regulations to the local maritime community by Local Notice to
Mariners and Broadcast Notice to Mariners.

2. Impact on Small Entities

    The Regulatory Flexibility Act of 1980 (RFA), 5 U.S.C. 601-612, as
amended, requires federal agencies to consider the potential impact of
regulations on small entities during rulemaking. The term ``small
entities'' comprises small businesses, not-for-profit organizations
that are independently owned and operated and are not dominant in their
fields, and governmental jurisdictions with populations of less than
50,000. The Coast Guard received zero comments from the Small Business
Administration on this rule. The Coast Guard certifies under 5 U.S.C.
605(b) that this rule will not have a significant economic impact on a
substantial number of small entities. This rule may affect the
following entities, some of which may be small entities: the owners or
operators of vessels intending to enter, transit through, anchor in, or
remain within any of the regulated areas during the respective
enforcement period. For the reasons discussed in the Regulatory
Planning and Review section above, this rule will not have a
significant economic impact on a substantial number of small entities.

3. Assistance for Small Entities

    Under section 213(a) of the Small Business Regulatory Enforcement
Fairness Act of 1996 (Pub. L. 104-121), we want to assist small
entities in understanding this rule. If the rule would affect your
small business, organization, or governmental jurisdiction and you have
questions concerning its provisions or options for compliance, please
contact the person listed in the FOR FURTHER INFORMATION CONTACT,
above.
    Small businesses may send comments on the actions of Federal
employees who enforce, or otherwise determine compliance with, Federal
regulations to the Small Business and Agriculture Regulatory
Enforcement Ombudsman and the Regional Small Business Regulatory
Fairness Boards. The Ombudsman evaluates these actions annually and
rates each agency's responsiveness to small business. If you

wish to comment on actions by employees of the Coast Guard, call 1-888-
REG-FAIR (1-888-734-3247). The Coast Guard will not retaliate against
small entities that question or complain about this rule or any policy
or action of the Coast Guard.

4. Collection of Information

    This rule will not call for a new collection of information under
the Paperwork Reduction Act of 1995 (44 U.S.C. 3501-3520).

5. Federalism

    A rule has implications for federalism under Executive Order 13132,
Federalism, if it has a substantial direct effect on the States, on the
relationship between the national government and the States, or on the
distribution of power and responsibilities among the various levels of
government. We have analyzed this rule under that Order and determined
that this rule does not have implications for federalism.

6. Protest Activities

    The Coast Guard respects the First Amendment rights of protesters.
Protesters are asked to contact the person listed in the FOR FURTHER
INTFORMATION CONTACT section to coordinate protest activities so that
your message can be received without jeopardizing the safety or
security of people, places or vessels.

7. Unfunded Mandates Reform Act

    The Unfunded Mandates Reform Act of 1995 (2 U.S.C. 1531-1538)
requires Federal agencies to assess the effects of their discretionary
regulatory actions. In particular, the Act addresses actions that may
result in the expenditure by a State, local, or tribal government, in
the aggregate, or by the private sector of $100,000,000 (adjusted for
inflation) or more in any one year. Though this rule will not result in
such an expenditure, we do discuss the effects of this rule elsewhere
in this preamble.

8. Taking of Private Property

    This rule will not cause a taking of private property or otherwise
have taking implications under Executive Order 12630, Governmental
Actions and Interference with Constitutionally Protected Property
Rights.

9. Civil Justice Reform

    This rule meets applicable standards in sections 3(a) and 3(b)(2)
of Executive Order 12988, Civil Justice Reform, to minimize litigation,
eliminate ambiguity, and reduce burden.

10. Protection of Children

    We have analyzed this rule under Executive Order 13045, Protection
of Children from Environmental Health Risks and Safety Risks. This rule
is not an economically significant rule and does not create an
environmental risk to health or risk to safety that may
disproportionately affect children.

11. Indian Tribal Governments

    This rule does not have tribal implications under Executive Order
13175, Consultation and Coordination with Indian Tribal Governments,
because it does not have a substantial direct effect on one or more
Indian tribes, on the relationship between the Federal Government and
Indian Tribes, or on the distribution of power and responsibilities
between the Federal Government and Indian tribes.

12. Energy Effects

    This action is not a ``significant energy action'' under Executive
Order 13211, Actions Concerning Regulations That Significantly Affect
Energy Supply, Distribution, or Use.

13. Technical Standards

    This rule does not use technical standards. Therefore, we did not
consider the use of voluntary consensus standards.

14. Environment

    We have analyzed this rule under Department of Homeland Security
Management Directive 023-01 and Commandant Instruction M16475.lD, which
guide the Coast Guard in complying with the National Environmental
Policy Act of 1969 (NEPA)(42 U.S.C. 4321-4370f). Due to potential
environmental issues, we conducted an environmental assessment last
year for both the issuance of the marine event permit and the
establishment of this special local regulation. The same environmental
assessment is being used for this year's event as it is substantially
similar in all aspects and therefore the potential effects and
alternatives remain unchanged. A supplemental environmental assessment
was conducted for changes to the annual reoccurring event. After
completing the supplemental environmental assessment for the issuance
of the marine event permit, and the establishment of this special local
regulation, we have determined that this action is one of a category of
actions that do not individually or cumulatively have a significant
effect on the human environment. This rule involves a special local
regulation issued in conjunction with a regatta or marine parade. This
rule is categorically excluded from further review under paragraph
34(h) of Figure 2-1 of the Commandant Instruction. The supplemental
environmental assessment, environmental assessment, and finding of no
significant impact (FONSI) are available in the docket where indicated
under ADDRESSES. We seek any comments or information that may lead to
the discovery of a significant environmental impact from this rule.

List of Subjects in 33 CFR Part 100

    Harbors, Marine safety, Navigation (water), Reporting and
recordkeeping requirements, Security Measures, Waterways.

    For the reasons discussed in the preamble, the Coast Guard amends
33 CFR part 100 as follows:

PART 100--SAFETY OF LIFE ON NAVIGABLE WATERS

0
1. The authority citation for part 100 continues to read as follows:

    Authority:  33 U.S.C. 1233.

0
2. Add a temporary Sec.  100.35T07-1073 to read as follows:

Sec.  100.35T07-1073  Special Local Regulation; 2013 Lauderdale Air
Show, Atlantic Ocean, Fort Lauderdale, FL.

    (a) Regulated areas. The following regulated areas are established
as a special local regulation. All coordinates are North American Datum
1983.
    (1) Exclusion area. All waters of the Atlantic Ocean in the
vicinity of Fort Lauderdale, Florida that are encompassed within an
imaginary line connecting the following points: starting at Point 1 in
position 26[deg]10'39'' N, 80[deg]05'47'' W; thence southeast to Point
2 in position 26[deg]10'32'' N, 80[deg]04'39'' W; thence southwest to
Point 3 in position 26[deg]06'33''N, 80[deg]05'08'' W; thence northwest
to Point 4 in position 26[deg]06'40'' N, 80[deg]06'15''W; thence
northeast back to origin.
    (2) Limited access area. All waters of the Atlantic Ocean in the
vicinity of Fort Lauderdale, Florida that are encompassed within an
imaginary line connecting the following points: starting at Point 1 in
position 26[deg]05'41'' N, 80[deg]06'59'' W; thence southeast to Point
2 in position 26[deg]05'26'' N, 80[deg]06'51'' W; thence northeast to
Point 3 in position 26[deg]05'32'' N, 80[deg]05'24'' W; thence north to
Point 4 in position 26[deg]05'42'' N, 80[deg]05'24'' W; thence
southwest back to origin.
    (b) Definition. The term ``designated representative'' means Coast
Guard Patrol Commanders, including Coast

Guard coxswains, petty officers, and other officers operating Coast
Guard vessels, and Federal, state, and local officers designated by or
assisting the Captain of the Port Miami in the enforcement of the
regulated area.
    (c) Regulations. (1) All persons and vessels, are prohibited from:
    (i) Entering, transiting through, anchoring in, or remaining within
the exclusion area, unless participating in the event.
    (ii) Transiting through, anchoring in, or remaining within the
limited access area, unless less than 500 gross tons.
    (2) Persons and vessels may request authorization to enter, transit
through, anchor in, or remain within the regulated areas by contacting
the Captain of the Port Miami by telephone at<PHONE_NUMBER>, or a
designated representative via VHF radio on channel 16. If authorization
is granted by the Captain of the Port Miami or a designated
representative, all persons and vessels receiving such authorization
must comply with the instructions of the Captain of the Port Miami or a
designated representative.
    (3) The Coast Guard will provide notice of the regulated areas by
Local Notice to Mariners, Broadcast Notice to Mariners, and on-scene
designated representatives.
    (d) Enforcement periods. The exclusion area will be enforced daily
from 10 a.m. until 5 p.m. from April 18, 2013, through April 21, 2013.
The limited access area will be enforced daily from 4 p.m. until 5:30
p.m. on April 20, 2013, and April 21, 2013.

    Dated: March 7, 2013.
C. P. Scraba,
Captain, U.S. Coast Guard, Captain of the Port Miami.
[FR Doc. 2013-06800 Filed 3-25-13; 8:45 am]
BILLING CODE 9110-04-P


[Federal Register Volume 78, Number 185 (Tuesday, September 24, 2013)]
[Proposed Rules]
[Pages 58492-58500]
[FR Doc No: 2013-23169]

=======================================================================
-----------------------------------------------------------------------

DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

18 CFR Part 40

[Docket No. RM13-16-000]

Generator Verification Reliability Standards

AGENCY: Federal Energy Regulatory Commission, DOE.

ACTION: Notice of proposed rulemaking.

-----------------------------------------------------------------------

SUMMARY: Pursuant to section 215 of the Federal Power Act, the Federal
Energy Regulatory Commission (Commission) proposes to approve the
following Reliability Standards that were submitted to the Commission
for approval by the North American Electric Reliability Corporation,
the Commission-certified Electric Reliability Organization: MOD-025-2
(Verification and Data Reporting of Generator Real and Reactive Power
Capability and Synchronous Condenser Reactive Power Capability), MOD-
026-1 (Verification of Models and Data for Generator Excitation Control
System or Plant Volt/Var Control Functions), MOD-027-1 (Verification of
Models and Data for Turbine/Governor and Load Control or Active Power/
Frequency Control Functions), PRC-019-1 (Coordination of Generating
Unit or Plant Capabilities, Voltage Regulating Controls, and
Protection), and PRC-024-1 (Generator Frequency and Voltage Protective
Relay Settings). The proposed generator verification Reliability
Standards help ensure that verified data is available for power system
planning and operational studies by requiring the verification of
generator equipment needed to support Bulk-Power System reliability and
enhance coordination of important protection system settings.
    The Commission proposes to approve, with modifications, the
associated implementation plans, violation risk factors and violation
severity levels. The Commission also proposes to approve the retirement
of existing Reliability Standards MOD-024-1 (Verification of Generator
Gross and Net Real Power Capability) and MOD-025-1 (Verification of
Generator Gross and Net Reactive Power Capability) prior to the
effective date of MOD-025-2.

DATES: Comments are due November 25, 2013.

ADDRESSES: You may submit comments, identified by docket number by any
of the following methods:
     Agency Web site: http://ferc.gov. Documents created
electronically using word processing software should be filed in native
applications or print-to-PDF format and not in a scanned format.
     Mail/Hand Delivery: Commenters unable to file comments
electronically must mail or hand deliver their comments to: Federal
Energy Regulatory Commission, Secretary of the Commission, 888 First
Street NE., Washington, DC 20426.

FOR FURTHER INFORMATION CONTACT: Mark Bennett (Legal Information),
Office of General Counsel, Federal Energy Regulatory Commission, 888
First Street NE., Washington, DC 20426,<PHONE_NUMBER>,
<EMAIL_ADDRESS>
    Syed Ahmad (Technical Information), Office of Electric Reliability,
Federal Energy Regulatory Commission, 888 First Street NE., Washington,
DC 20426,<PHONE_NUMBER><EMAIL_ADDRESS>
SUPPLEMENTARY INFORMATION:

Notice of Proposed Rulemaking

(Issued September 19, 2013)

    1. Under section 215 of the Federal Power Act (FPA) \1\ the
Commission proposes to approve five Reliability Standards that were
submitted to the Commission for approval by the North American Electric
Reliability Corporation (NERC), the Commission-certified Electric
Reliability Organization (ERO): MOD-025-2 (Verification and Data
Reporting of Generator Real and Reactive Power Capability and
Synchronous Condenser Reactive Power Capability), MOD-026-1
(Verification of Models and Data for Generator Excitation Control
System or Plant Volt/Var Control Functions), MOD-027-1 (Verification of
Models and Data for Turbine/Governor and Load Control or Active Power/
Frequency Control Functions), PRC-019-1 (Coordination of Generating
Unit or Plant Capabilities, Voltage Regulating Controls, and
Protection), and PRC-024-1 (Generator Frequency and Voltage Protective
Relay Settings). The Commission proposes to approve, with
modifications, the associated implementation plans, violation risk
factors and violation severity levels. The Commission also proposes to
approve the retirement of existing Reliability Standards MOD-024-1 and
MOD-025-1 immediately prior to the effective date of MOD-025-2.
---------------------------------------------------------------------------

    \1\ 16 U.S.C. 824o (2006).
---------------------------------------------------------------------------

    2. The purpose of the proposed Reliability Standards is to ensure
that generators remain in operation during specified voltage and
frequency excursions; properly coordinate protective relays and
generator voltage regulator controls; and ensure that

generator models accurately reflect the generator's capabilities and
equipment performance. Proposed Reliability Standards MOD-026-1, MOD-
027-1, PRC-019-1 and PRC-024-1 are new whereas proposed Reliability
Standard MOD-025-2 consolidates two existing standards, MOD-024-1
(Verification of Generator Gross and Net Real Power Capability) and
MOD-025-1 (Verification of Generator Gross and Net Reactive Power
Capability) into one new Reliability Standard. Portions of proposed
Reliability Standards MOD-025-2 and PRC-024-1 respond to Commission
directives issued in Order No. 693.\2\
---------------------------------------------------------------------------

    \2\ See Mandatory Reliability Standards for the Bulk-Power
System, Order No. 693, FERC Stats. & Regs. ] 31,242, order on reh'g,
Order No. 693-A, 120 FERC ] 61,053 (2007).
---------------------------------------------------------------------------

    3. Collectively, the proposed Reliability Standards improve the
accuracy of model verifications needed to support reliability and
enhance the coordination of generator protection systems and voltage
regulating system controls. Such improvements should help reduce the
risk of generator trips and provide more accurate models for
transmission planners and planning coordinators to develop system
models and simulations.
    4. In contrast to the greater than 20 MVA applicability threshold
for the three other proposed Reliability Standards in NERC's petition,
proposed standards MOD-026-1 and MOD-027-1 would exclude units rated
below 100 MVA (Eastern and Quebec Interconnections), 75 MVA (Western
Interconnection) and 50 MVA (ERCOT Interconnection). This difference in
applicability thresholds could exclude approximately 20 percent of
registered generator owners/operators from compliance. The Commission
seeks comment on whether the higher applicability thresholds limit the
overall effectiveness of the proposed Reliability Standards, especially
in areas with a high concentration of generators falling below the
thresholds.
    5. Further, proposed Reliability Standard MOD-026-1 contains a
provision allowing transmission planners to compel certain generator
owners to comply with the proposed standard's Requirements if the
generator owners are deemed to have ``technically justified'' units,
even if the generators fall below the stated applicability threshold.
The Commission seeks comment on this proposed process, and also seeks
comment regarding whether this provision should be included in proposed
Reliability Standard MOD-027-1.

I. Background

Section 215 of the FPA and Order No. 693 Directives

    6. Section 215 of the FPA requires a Commission-certified ERO to
develop mandatory and enforceable Reliability Standards, subject to
Commission review and approval. Specifically, the Commission may
approve, by rule or order, a proposed Reliability Standard or
modification to a Reliability Standard if it determines that the
Reliability Standard is just, reasonable, not unduly discriminatory or
preferential, and in the public interest.\3\ Once approved, the
Reliability Standards may be enforced by the ERO, subject to Commission
oversight, or by the Commission independently.\4\
---------------------------------------------------------------------------

    \3\ 16 U.S.C. 824o(d)(2).
    \4\ Id. 824o(e)(3).
---------------------------------------------------------------------------

    7. Pursuant to section 215 of the FPA, the Commission established a
process to select and certify an ERO,\5\ and subsequently certified
NERC.\6\ On March 16, 2007, the Commission issued Order No. 693,
approving 83 of the 107 Reliability Standards filed by NERC. Because
MOD-024-1 and MOD-025-1, which NERC had included in its filing,
involved regional procedures that had not been submitted, the
Commission postponed either approving or remanding these standards
until NERC submitted additional information. However, the Commission
issued directives in Order No. 693 with respect to MOD-024-1 and MOD-
025-1 that NERC states are addressed in proposed Reliability Standard
MOD-025-2.
---------------------------------------------------------------------------

    \5\ Rules Concerning Certification of the Electric Reliability
Organization; and Procedures for the Establishment, Approval, and
Enforcement of Electric Reliability Standards, Order No. 672, FERC
Stats. & Regs. ] 31,204, order on reh'g, Order No. 672-A, FERC
Stats. & Regs. ] 31,212 (2006).
    \6\ North American Electric Reliability Corp., 116 FERC ]
61,062, order on reh'g and compliance, 117 FERC ] 61,126 (2006),
aff'd sub nom. Alcoa, Inc. v. FERC, 564 F.3d 1342 (D.C. Cir. 2009).
---------------------------------------------------------------------------

    8. Reliability Standards MOD-024-1 and MOD-025-1 were ``fill-in-
the-blank'' Reliability Standards that required regional reliability
organizations to develop procedures to verify generator real and
reactive power capability, respectively. Regarding MOD-024-1, the
Commission directed NERC to clearly define the test conditions and
methodologies contained in the Reliability Standard, and also to
clarify the time period within which regional reliability organizations
must provide generator real power capability verification.\7\ For MOD-
025-1, the Commission directed NERC to clarify that MVAR capability
verifications should be made at multiple points over a generator unit's
operating range, and also directed NERC to clarify the time period
within which reactive power capability verifications are to be
provided.\8\
---------------------------------------------------------------------------

    \7\ Order No. 693, FERC Stats. & Regs. ] 31,242 at PP 1310-1311.
    \8\ Id. PP 1321-1323.
---------------------------------------------------------------------------

    9. Two directives contained in Order No. 693 pertain to proposed
Reliability Standard PRC-024-1. When discussing NERC's proposed TPL
Reliability Standards, the Commission stated that NERC should use the
Nuclear Regulatory Commission's (NRC) voltage ride through requirements
when implementing Reliability Standards to ``assure that there is
consistency between the Reliability Standards and the NRC requirement
that the system is accurately modeled.'' \9\ The Commission further
directed NERC to explicitly require generators to be ``capable of
riding through the same set of Category B and C contingencies, as
required by wind generators in Order No. 661, or that those generators
that cannot ride through be simulated as tripping.'' \10\
---------------------------------------------------------------------------

    \9\ Id. P 1787.
    \10\ Id.
---------------------------------------------------------------------------

II. NERC Petition and Proposed Reliability Standards

A. NERC Petition

    10. On May 30, 2013, NERC filed a petition seeking approval of
proposed Reliability Standards MOD-025-2, MOD-026-1, MOD-027-1, PRC-
019-1 and PRC-024-1. Four of the five Reliability Standards are new,
while existing Reliability Standards MOD-024-1 and MOD-025-1 were
merged into proposed Reliability Standard MOD-025-2. NERC also seeks
approval of the associated implementation plans, violation risk factors
and violation severity levels, and retirement of current Reliability
Standards MOD-024-1 and MOD-025-1 at midnight of the day immediately
prior to the effective date of MOD-025-2. NERC proposes to phase in
effective dates in stages over periods ranging from five years (for
MOD-025-2, PRC-019-1 and PRC-024-1) to ten years (for MOD-026-1 and
MOD-027-1).\11\ NERC states that ``these five proposed Reliability
Standards address generator verifications needed to support Bulk-Power
System reliability and will ensure that accurate data is verified and
made available for planning simulations.'' \12\
---------------------------------------------------------------------------

    \11\ NERC Petition, Exhibit B.
    \12\ NERC Petition at 2.
---------------------------------------------------------------------------

    11. NERC explains that Bulk-Power System reliability benefits from
``good quality simulation models of power system equipment,'' and that
``model validation ensures the proper

performance of the control systems and validates the computer models
used for stability analysis.'' \13\ NERC further states that the
proposed Reliability Standards will enhance reliability because the
tests performed to obtain model data may reveal latent defects that
could cause ``inappropriate unit response during system disturbances.''
\14\ NERC also states that simulating the response of synchronous
machines and related control systems in sufficient detail is essential
for effective power system planning and operational studies.\15\ For
accurate simulations reflecting actual equipment performance covering a
range of disturbances, NERC states that models must not only contain
adequate information, they must also correspond to actual field
values.\16\
---------------------------------------------------------------------------

    \13\ Id.
    \14\ Id. at 2-3.
    \15\ Id. at 3.
    \16\ Id.
---------------------------------------------------------------------------

B. Proposed Reliability Standards

1. Reliability Standard MOD-025-2
    12. Proposed Reliability Standard MOD-025-2 merges two existing
Reliability Standards, MOD-024-1 and MOD-25-1, and has the stated
purpose of ensuring the accuracy of generator information related to
gross and net real and reactive power capability and synchronous
condenser reactive power capability that is available for planning
models and bulk electric system reliability assessments.\17\ The
proposed Reliability Standard applies to generator owners and
transmission owners that own synchronous condensers, and has three
requirements and two Attachments. Attachment 1, incorporated into
Requirements R1.1, R2.1 and R3.1, specifies the periodicity for
performing real and reactive power capability verification and the
verification specifications for applicable facilities. Attachment 2,
which generator owners and transmission owners will use to report to
their transmission planners the information described in Attachment 1,
is incorporated into Requirements R1.2, R2.2 and R3.2.
---------------------------------------------------------------------------

    \17\ Reliability Standard MOD-025-2, Section A.3 (Purpose).
---------------------------------------------------------------------------

    13. NERC states that proposed Reliability Standard MOD-025-2
addresses the directives the Commission issued in Order No. 693.
Specifically, NERC states:
    (1) Requirement R1, Part 1.2 specifies that a generator owner must
submit Attachment 2 or another form containing the same information to
its transmission planner within 90 calendar days of either the date the
data is recorded for a staged test or the date the data is selected for
verification using historical operational data; (2) Requirement R1,
Part 1.1 requires a generator owner to verify the real power capability
of its generating units as set forth in Attachment 1, including the
consideration of ambient conditions during the verification period; and
(3) Attachment 1, Sections 2.1 through 2.4, requires reactive power
capability verification at multiple points across a unit's operating
range.\18\
---------------------------------------------------------------------------

    \18\ NERC Petition at 10-12.
---------------------------------------------------------------------------

2. Reliability Standard MOD-026-1
    14. Proposed Reliability Standard MOD-026-1, which is applicable to
generator owners and transmission planners, is a new Reliability
Standard that has six requirements and an Attachment describing the
periodicity for excitation control system or plan volt/var function
model verification. NERC explains that the purpose of proposed
Reliability Standard MOD-026-1 is to ensure that detailed modeling of
generator excitation systems, essential for valid simulations in power
system stability studies, will be conducted, and that those models
accurately represent generator excitation control system or plant volt/
var control function behavior for bulk electric system reliability
assessments.\19\ Requirement R1 requires transmission planners to
provide generator owners with specified information within 90 days of a
written request, including instructions on how to obtain models, block
diagrams and/or data sheets and model data for any of the generator
owner's existing applicable unit specific excitation control system or
plant volt/var control function contained in the transmission planner's
dynamic database from the current (in-use) models. NERC explains that
Requirement R1 ensures that the transmission planner provides necessary
information to the generator owners so that they can provide a useable
model in an acceptable format. This further ensures that generator
owners can comply with Requirement R2 by providing relevant information
to transmission planners.\20\
---------------------------------------------------------------------------

    \19\ Id. at 14-16.
    \20\ Id. at 15.
---------------------------------------------------------------------------

    15. Requirement R2 requires each generator owner to provide its
transmission planner with a verified generator excitation control
system or plant volt/var control function model that includes the data
and documentation specified in Requirement R2, Part 2.1. The
periodicity for this requirement is set forth in Attachment 1. The
purpose of Requirement R2 is to verify that the generator excitation
control system or plant volt/var control function model and the model
parameters used in dynamic simulations performed by the transmission
planner accurately represent the generator excitation control system or
plant volt/var control function behavior when assessing bulk electric
system reliability.\21\ Requirement R3 requires generator owners to
provide written responses to transmission planner requests within 90
days regarding unusable models, technical concerns and transmission
planner determinations that simulated excitation control system or
plant volt/var control function model responses do not match a recorded
response to a transmission system event. NERC explains that Requirement
R3 of proposed Reliability Standard MOD-026-1 ``provides response
requirements for a Generator Owner when it receives certain requests
from the Transmission Planner. This communication ensures that
Generator Owners have an obligation to respond in a timely fashion when
there are demonstrated problems with a model that was provided by the
Generator Owner in accordance with Requirement R2.'' \22\ Under
Requirement R4, generator owners are required to determine whether
changes to applicable units affect models provided pursuant to
Requirement R2, and to provide the transmission planner with revised
model data or plans to perform model verification.
---------------------------------------------------------------------------

    \21\ Id. at 16.
    \22\ Id. at 17.
---------------------------------------------------------------------------

    16. Requirement R5 requires a generator owner to respond within 90
days to a ``technically justified unit request'' from its transmission
planner to perform a model review of a unit or plant, including details
for model verification or corrected model data. A footnote to
Requirement R5 states that ``Technical justification is achieved by the
Transmission Planner demonstrating that the simulated unit or plant
response does not match the measured unit or plant response.'' Also,
Applicability section 4.2.4 in MOD-026-1 states that facilities to
which the standard applies include ``For all Interconnections: A
technically justified unit that meets NERC registry criteria but is not
otherwise included in the above Applicability sections 4.2.1, 4.2.2, or
4.2.3 and is requested by the Transmission Planner.''
    17. NERC explains that Requirement R5 allows transmission planners
to request that generator owners who otherwise are not covered by the

Applicability section (i.e., whose MVA ratings are lower than the
applicability thresholds specified in Section 4 of proposed Reliability
Standard MOD-026-1 but meet or exceed the Registry Criteria) to provide
model verifications or to correct model data.\23\ Requirement R6
requires transmission planners to provide written responses to
generator owners within 90 days of receiving a verified excitation
control system or plant volt/var control function model information
whether the model is usable or not in accordance with Requirement R2.
If it determines the model to be unusable, the transmission planner
must explain the technical basis for that decision.
---------------------------------------------------------------------------

    \23\ Id. at 18.
---------------------------------------------------------------------------

3. Reliability Standard MOD-027-1
    18. The stated purpose of proposed Reliability Standard MOD-027-1,
which is new and contains five Requirements and an Attachment, is to
verify that the turbine/governor and load control or active power/
frequency control model and the model parameters, used in dynamic
simulations that assess bulk electric system reliability, accurately
represent generator unit real power response to system frequency
variations.\24\ Requirement R1 requires transmission planners to
provide generator owners with guidance that will enable generator
owners to provide the information required in Requirements R2 and R4
within 90 days of a written request. Requirement R2 requires generator
owners to provide transmission planners with a verified turbine/
governor and load control or active power/frequency control model for
each applicable unit, including documentation and data in accordance
with the periodicity specified in MOD-027-1 Attachment 1. Attachment 1
(Turbine/Governor and Load Control or Active Power/Frequency Control
Model Periodicity) also contains a table listing verification
conditions and related actions required of generator owners.\25\
---------------------------------------------------------------------------

    \24\ Reliability Standard MOD-27-1, Section A.3 (Purpose).
    \25\ NERC Petition at 20.
---------------------------------------------------------------------------

    19. Requirement R3 establishes communication requirements to ensure
that generator owners respond to transmission planner determinations
that a generator owner's model is not ``usable,'' or where there is a
difference between the model and three or more actual transmission
system events.\26\ Requirement R4 requires generator owners to provide
transmission planners with updates when changes occur to the turbine/
governor and load control or active power/frequency control system that
alter equipment response characteristics.\27\ Requirement R5 requires
transmission planners to inform generator owners within 90 days of
receiving model information (in accordance with Requirement R2) whether
the model is usable or not. If a model is unusable, the transmission
planner shall provide the generator owner with an explanation of the
technical basis for that decision. Also, Requirement R3 requires
generator owners to provide a written response within 90 days.\28\
---------------------------------------------------------------------------

    \26\ Id. at 21.
    \27\ Id. at 22.
    \28\ Id.
---------------------------------------------------------------------------

4. Proposed Reliability Standard PRC-019-1
    20. Proposed Reliability Standard PRC-019-1 is new and contains two
requirements intended to ensure that both generator owners and
transmission owners verify coordination of generating unit facility or
synchronous condenser voltage regulating controls, limit functions,
equipment capabilities and protection system settings.\29\ Requirement
R1 requires generator owners and transmission owners to coordinate the
voltage regulating system controls with the equipment capabilities and
settings of the applicable protection system devices and functions.\30\
Requirement R2 requires generator owners and transmission owners to
perform the coordination described in Requirement R1 to address
equipment or setting changes.\31\ The coordination required in proposed
Reliability Standard PRC-019-1 must be performed at least every five
years.
---------------------------------------------------------------------------

    \29\ Reliability Standard PRC-019-1, Section A.3 (Purpose).
    \30\ NERC Petition at 23.
    \31\ Id. at 24.
---------------------------------------------------------------------------

5. Proposed Reliability Standard PRC-024-1
    21. Proposed Reliability Standard PRC-024-1 is new and consists of
four Requirements and two Attachments. The stated purpose of PRC-024-1
is to ensure that generator owners set their generator protective
relays such that generating units remain connected during defined
frequency and voltage excursions.\32\ Requirement R1 requires generator
owners having generator frequency protective relaying activated to trip
their generating units to set their protective relaying to prevent
their generating units from tripping within the ``no trip zone'' of
PRC-024-1 Attachment 1 (unless one of three specified exceptions
applies). NERC explains that Attachment 1 contains tables with curve
data points for each Interconnection indicating the amount of time a
generator needs to remain connected at specific defined frequency
excursions.\33\ Requirement R2 addresses voltage excursions, requiring,
subject to four exceptions, generator owners to ensure that their
voltage protective relaying settings prevent their generating units
from tripping within the ``no trip zone'' described in PRC-024-1,
Attachment 2.
---------------------------------------------------------------------------

    \32\ Reliability Standard PRC-024-1, Section A.3 (Purpose).
    \33\ NERC Petition at 25.
---------------------------------------------------------------------------

    22. NERC states that the standard drafting team believes the
voltage profile contained in Attachment 2 includes excursions that
would be expected under Category B and C contingencies. Therefore, NERC
asserts that by ensuring that generator units remain connected to the
grid during voltage excursions, Requirement R2 and Attachment 2 satisfy
the Commission directive issued in Order No. 693 to ``explicitly
require either that all generators are capable of riding through the
same set of Category B and C contingencies, as required by wind
generators in Order No. 661, or that those generators that cannot ride
through be simulated as tripping.'' \34\
---------------------------------------------------------------------------

    \34\ Id. at 29 (citing Order No. 693, FERC Stats. & Regs. ]
31,242 at P 1787).
---------------------------------------------------------------------------

    23. Requirement R3 of proposed Reliability Standard PRC-024-1
requires generator owners to document regulatory or equipment
limitations that would prevent them from satisfying the relay setting
criteria in Requirements R1 and R2. Generator owners must inform their
planning coordinator and transmission planner of such limitations
within 30 calendar days. According to NERC, the standard drafting team
believes that ``regulatory limitations'' include NRC requirements and,
therefore, Requirement R3 satisfies the Commission's guidance that
``NRC requirements should be used when implementing the Reliability
Standards.'' \35\
---------------------------------------------------------------------------

    \35\ Id. at 27-28 (citing Order No. 693, FERC Stats. & Regs. ]
31,242 at P 1787).
---------------------------------------------------------------------------

    24. Requirement R4 requires generator owners to provide their
planning coordinator or transmission planner with generator protection
trip settings associated with Requirements R1 and R2 within 60 days of
either a written request or a change to previously requested trip
settings.\36\
---------------------------------------------------------------------------

    \36\ Id. at 31.
---------------------------------------------------------------------------

III. Discussion

    25. Pursuant to section 215(d) of the FPA, the Commission proposes
to approve proposed Reliability Standards

MOD-025-2, MOD-026-1, MOD-027-1, PRC-019-1 and PRC-024-1, including the
associated implementation plan and proposed violation risk factors and
violations severity levels, as just, reasonable, not unduly
discriminatory or preferential, and in the public interest. The
proposed Reliability Standards help ensure that verified data is
available for power system planning and operational studies by
requiring the verification of generator equipment needed to support
Bulk-Power System reliability and enhance coordination of important
protection system settings. Also, proposed Reliability Standards MOD-
025-2 and PRC-024-1 satisfy relevant outstanding directives set forth
in Order No. 693. We also propose to approve the retirement of the
currently-effective standards MOD-024-1 and MOD-025-1 prior to the
effective date of MOD-025-2.
    26. While we propose to approve the proposed Reliability Standards,
we seek comment on certain aspects of proposed Reliability Standards
MOD-026-1 and MOD-027-1. Specifically, we discuss the following issues
below: (A) The higher Megavolt Amperes (MVA) applicability threshold
for proposed Reliability Standards MOD-026-1 and MOD-027-1; (B) the
process for determining when it is ``technically justified'' for a
transmission planner to require a generator owner to provide model
reviews under MOD-026-1; (C) why the ``technically justified''
provision is not also included in MOD-027-1; and (D) assignment of
violation of severity levels.

A. Higher MVA Applicability Threshold in MOD-026-1 and MOD-027-1

    27. The applicability thresholds in proposed Reliability Standards
MOD-026-1 and MOD-027-1 are higher than for the other three proposed
Reliability Standards, and could exclude approximately 20 percent of
generators from compliance.\37\ In contrast to the greater than 20 MVA
applicability thresholds set forth in the other three proposed
Reliability Standards in NERC's petition,\38\ MOD-026-1 and MOD-027-1
would exclude units rated below 100 MVA (Eastern and Quebec
Interconnection), 75 MVA (Western Interconnection) and 50 MVA (ERCOT
Interconnection).\39\
---------------------------------------------------------------------------

    \37\ See NERC Petition, Exhibit E (Summary of the Reliability
Standard Development Proceeding and Complete Record of Development
of Proposed Reliability Standard) section entitled ``Consideration
of Comments on Draft Standard'' at 91 indicating that the threshold
in the proposed standard would limit applicability of the standard
to 80 percent of installed MVA on an Interconnection basis.
    \38\ Reliability Standard MOD-025-2, Section 4.2 (Facilities);
Reliability Standard PRC-019-1, Section 4.2 (Facilities); and
Reliability Standard PRC-024-1, Section 4 (Applicability).
    \39\ Reliability Standard MOD-026-1, Section 4.2 (Facilities);
Reliability Standard MOD-027-1, Section 4.2 (Facilities).
---------------------------------------------------------------------------

    28. During the standard development process, several industry
stakeholders commented that the standard drafting team should ensure
that the applicability thresholds of MOD-026-1 and MOD-027-1 be aligned
with the other three proposed Reliability Standards. In response, the
standard drafting team stated that ``verification of excitation system
is expensive both from a monetary and human resource viewpoint.
Therefore, the [standard drafting team] believes that these
applicability thresholds will result in substantial accuracy
improvements to the excitation models and associated Reliability
Standards, while not unduly mandating costly and time-consuming
verification efforts.'' \40\ We seek comment as to whether excluding
approximately 20 percent of generators from the applicability of MOD-
026-1 and MOD-027-1, especially in areas with a high concentration of
generators falling below the thresholds, would (a) limit the
effectiveness of proposed Reliability Standards MOD-026-1 and MOD-027-1
or (b) adversely impact transmission planners' ability to reduce risk
to Bulk Power System reliability.
---------------------------------------------------------------------------

    \40\ NERC Petition, Exhibit E (Summary of the Reliability
Standard Development Proceeding and Complete Record of Development
of Proposed Reliability Standard) section entitled ``Consideration
of Comments on Draft Standard'' at 91.
---------------------------------------------------------------------------

B. Process for Identifying ``Technically Justified'' Generating Units
in MOD-026-1

    29. Proposed Reliability Standard MOD-026-1 applies to generating
units that are connected to the bulk electric system when ``technically
justified.'' Specifically, Applicability Section 4.2.4 allows a
transmission planner to compel a generator owner to provide model
reviews and related information in accordance with Requirement R5 if
the transmission planner's unit simulations do not match the generator
owner's measured unit data. Under such circumstances, generator owners
with ``technically justified'' units must comply with proposed
Reliability Standard MOD-026-1, even though the unit MVA rating is
below the stated MVA threshold for applicability.
    30. While we agree with the intent of this section, the means by
which transmission planners would become aware of discrepancies between
simulated units and measured units, which forms the basis for
``technically justified'' determinations, is unclear. The technical
justification, or discrepancies between simulated units and measured
units, suggests that there should be some benchmark available in the
process by which transmission planners identify generator owners for
compliance with MOD-026-1. The Final Report on the August 2003 blackout
stated that ``the regional councils are to establish and begin
implementing criteria and procedures for validating data used in power
flow models and dynamic simulations by benchmarking model data with
actual system performance.'' \41\ The Commission seeks comment from
NERC and other interested parties as to whether the means or process
for transmission planners to determine whether a generator owner's unit
is ``technically justified'' is sufficiently clear and workable. We
further seek comment as to whether additional details regarding how the
process will be implemented should be included in an attachment to the
proposed Reliability Standard.
---------------------------------------------------------------------------

    \41\ U.S.-Canada Power System Outage Task Force (Task Force),
Final Report on the August 14, 2003 Blackout in the United States
and Canada: Causes and Recommendations (April 2004) (Final Blackout
Report), Recommendation 24. The Final Blackout Report is available
on the Internet at http://www.ferc.gov/industries/electric/indus-act/blackout.asp.
---------------------------------------------------------------------------

C. Should Proposed Reliability Standard MOD-027-1 Include the
``Technically Justified'' Provision

    31. Proposed Reliability Standard MOD-027-1 does not contain a
provision analogous to section 4.2.4 of MOD-026-1, whereby a
transmission planner may determine whether to subject a generator owner
with units falling below the stated applicability threshold to the
Requirements in proposed Reliability Standard MOD-026-1. We seek
comment as to whether the technical justification provision should also
be included in proposed Reliability Standard MOD-027-1 to provide an
opportunity for transmission planners to address discrepancies between
unit simulations and generator owners' measured unit data.

D. Violation Severity Levels

1. VSL for MOD-026-1, Requirement R6 and MOD-027-1, Requirement R5
    32. For Requirement R6 of MOD-026-1 and Requirement R5 of MOD-027-
1, NERC proposes a ``severe'' violation severity level when a
transmission planner's written response that a Generation Owner's
verified model is useable ``omitted confirmation for all

specified model criteria'' in the requirement. NERC does not propose
any violation severity level for a violation of the last sentence of
these requirements: ``If the model is not useable, the [transmission
planner] shall provide a technical description of why the model is not
useable.'' Compliance with this sentence is equally important as
compliance with the other obligations of these Requirements. Lack of a
violation severity level for this type of violation is inconsistent
with our VSL Guideline 3 because the proposed violation severity levels
do not address all obligations in these Requirements. We propose to
direct that NERC submit a violation severity level that addresses a
violation of the last sentence of Requirement R6 of MOD-026-1 and
Requirement R5 of MOD-027-1.
2. VSL for PRC-024-1, Requirements R1 and R2
    33. NERC proposes to assign a ``severe'' violation severity level
for a violation of Requirements R1 and R2 of PRC-024-1 when a generator
owner fails to set its generator frequency or voltage protective relays
so that they do not trip within the criteria listed within Requirements
R1 and R2 unless there is a documented and communicated regulatory or
equipment limitation per Requirement R3. We observe that Requirements
R1 and R2 of PRC-024-1 include three and four bulleted exceptions,
respectively, to the requirement that the generator frequency or
voltage protective relays not trip applicable generating unit(s) within
the ``no-trip zone'' of Attachment 1 or 2 to that standard. For
Requirements R1 and R2, only the third and fourth exception,
respectively, relate to a regulatory or equipment limitation in
accordance with Requirement R3. As a result, the wording of the
violation severity level for Requirements R1 and R2 could be read to
mean that a generator owner that set generator frequency or voltage
protective relaying to trip within the ``no-trip zone'' based on either
the first or second exception in Requirement R1 and either the first,
second or third exception in R2, violated that Requirement with a
severe violation severity level. To avoid that interpretation, NERC
should confirm in its comments that a generator owner will not violate
Requirement R1 or R2 if it sets generator frequency or voltage
protective relaying to trip within the ``no-trip zone'' based upon the
exceptions for Requirements R1 and R2.

IV. Information Collection Statement

    34. The following collection of information contained in the
Proposed Rule is subject to review by the Office of Management and
Budget (OMB) under section 3507(d) of the Paperwork Reduction Act of
1995 (PRA).\42\ OMB's regulations require that OMB approve certain
reporting and recordkeeping requirements (collections of information)
imposed by an agency.\43\ Upon approval of a collection of information,
OMB will assign an OMB control number and expiration date. Respondents
subject to the filing or recordkeeping requirements of this rule will
not be penalized for failing to respond to these collections of
information unless the collections of information display a valid OMB
control number.
---------------------------------------------------------------------------

    \42\ 44 U.S.C. 3507(d) (2006).
    \43\ 5 CFR 1320.11 (2013).
---------------------------------------------------------------------------

    35. The Commission will submit these reporting and recordkeeping
requirements to OMB for its review and approval under section 3507(d)
of the PRA. Comments are solicited on the Commission's need for this
information, whether the information will have practical utility, the
accuracy of the provided burden estimate, ways to enhance the quality,
utility, and clarity of the information to be collected, and any
suggested methods for minimizing the respondents' burden, including the
use of automated information techniques.
    36. This Notice of Proposed Rulemaking proposes to approve five
proposed Reliability Standards: MOD-025-2, MOD-026-1, MOD-027-1, PRC-
019-1 and PRC-024-1. Proposed Reliability Standard MOD-025-2 would
replace currently effective Reliability Standards MOD-024-1 and MOD-
025-1. In Order No. 693, the Commission did not approve or remand MOD-
024-1 and MOD-025-1, as they were identified as ``fill-in-the-blank''
Reliability Standards for which NERC had not submitted regional
procedures.
    37. Public Reporting Burden: The burden and cost estimates below
are based on the increase in the reporting and recordkeeping burden
imposed by the proposed Reliability Standards. Our estimate of the
number of respondents affected is based on the NERC Compliance Registry
as of July 30, 2013.\44\ According to the Compliance Registry, NERC has
registered 901 generator owners within the United States. Currently,
synchronous condensers are not included in the NERC Compliance
Registry, and the standard drafting team stated that the number of
transmission owners who own synchronous condensers is extremely low. We
seek NERC and industry comment regarding the number of synchronous
condensers currently in use (including confidential data, if
necessary).
---------------------------------------------------------------------------

    \44\ NERC Compliance Registry (July 30, 2013), available at
http://www.nerc.com/pa/comp/Registration%20and%20Certification%20DL/NERC_Compliance_Registry_Matrix_Summary20130730.pdf.
    \45\ GO = Generator Owner, TP = Transmission Planner.
    Assuming 10 generators per generator owner, using EIA-860 2012
generator data (http://www.eia.gov/electricity/data/eia860/) total
number of units > 20 MW are 7,379, which results in 738 generator
owners.
    \46\ The estimates for cost per hour are derived as follows:
    $52/hour, the average of the salary plus benefits for an
engineer, from Bureau of Labor and Statistics at http://bls.gov/oes/current/naics3_221000.htm.
    $70/hour, the average of the salary plus benefits for a manager
and an engineer, from Bureau of Labor and Statistics at http://bls.gov/oes/current/naics3_221000.htm.
    $28/hour, based on a Commission staff study of record retention
burden cost.
---------------------------------------------------------------------------

    38. The burden estimates reflect the standards and the number of
affected entities (e.g., the generator owner's one-time burden to
develop testing procedures, verification process, and process for
collection of data). Estimates for the additional burden imposed by the
NOPR, if approved as a final rule in RM13-16, follow.

--------------------------------------------------------------------------------------------------------------------------------------------------------
                                                               Number of       Number of        Average
                         FERC-725G                            respondents    responses per   burden hours    Total annual      Total annual cost \46\
                                                                 \45\         respondent     per response    burden hours
                                                                       (1)             (2)             (3)     (1)x(2)x(3)
--------------------------------------------------------------------------------------------------------------------------------------------------------
                     PRC-019-1 (Coordination of Generating Unit or Plant Capabilities, Voltage Regulating Controls, and Protection)
--------------------------------------------------------------------------------------------------------------------------------------------------------
Develop coordination and relay settings procedures........             738               1               8           5,904  $307,008 one-time ($52/hr).
                                                                        GO

Relay Settings............................................             738               1               8           5,904           413,280 (70/hr).
                                                                        GO
Evidence Retention \46\...................................             738               1               1             738            20,664 (28/hr).
                                                                        GO
                                                                                -------------------------------------------------------------
    TOTAL.................................................  ..............  ..............  ..............          12,546            740,952
--------------------------------------------------------------------------------------------------------------------------------------------------------
                                          PRC-024-1 (Generator Frequency and Voltage Protective Relay Settings)
--------------------------------------------------------------------------------------------------------------------------------------------------------
Develop coordination and relay settings procedures........             738               1               8           5,904  307,008 one-time (52/hr).
                                                                        GO
Relay Settings............................................             738               1               8           5,904           413,280 (70/hr).
                                                                        GO
Evidence Retention \46\...................................             738               1               1             738            20,664 (28/hr).
                                                                        GO
                                                                                -------------------------------------------------------------
    TOTAL.................................................  ..............  ..............  ..............          12,546            740,952
--------------------------------------------------------------------------------------------------------------------------------------------------------

--------------------------------------------------------------------------------------------------------------------------------------------------------
                                                           Number of       Number of        Average
                       FERC-725L                          respondents    responses per   burden hours    Total annual        Total annual cost \46\
                                                             \45\         respondent     per response    burden hours
                                                                   (1)             (2)             (3)     (1)x(2)x(3)
--------------------------------------------------------------------------------------------------------------------------------------------------------
     MOD-025-2 (Verification and Data Reporting of Generator Real and Reactive Power Capability and Synchronous Condenser Reactive Power Capability)
--------------------------------------------------------------------------------------------------------------------------------------------------------
Develop testing procedures, verification process, and              738               1               8     5,904 (one-  $307,008 one-time ($52/hr).
 process for collection of data.......................              GO                                           time)
Attachment 2..........................................             738               1               6           4,428     309,960 (70/hr).
                                                                    GO
Evidence Retention \46\...............................             738               1               1             738      20,664 (28/hr).
                                                                    GO
                                                                                -----------------------------------------------------------------
    TOTAL.............................................  ..............  ..............  ..............          11,070      637,632
--------------------------------------------------------------------------------------------------------------------------------------------------------
Develop testing procedures, verification process, and              356               1               8     2,848 (one-  148,096 one-time (52/hr).
 process for collection of data.......................              GO                                           time)
Instructions for obtaining excitation control system               187               1               8           1,496     104,720 (70/hr).
 or plant voltage/variance control function model.....              TP
Documentation on generator verification...............             356               1               8           2,848     199,360 (70/hr).
                                                                    GO
Evidence Retention \46\...............................             543               1               1             543      15,204 (28/hr).
                                                             GO and TP
                                                                                -----------------------------------------------------------------
TOTAL.................................................  ..............  ..............  ..............           7,735      467,380
--------------------------------------------------------------------------------------------------------------------------------------------------------
              MOD-027-1 (Verification of Models and Data for Turbine/Governor and Load Control or Active Power/Frequency Control Functions)
--------------------------------------------------------------------------------------------------------------------------------------------------------
Develop testing procedures, verification process, and              356               1               8     2,848 (one-  $148,096 one-time (52/hr).
 process for collection of data.......................              GO                                           time)
Instructions for obtaining turbine/governor and load               187               1               8           1,496     104,720 (70/hr).
 control or active power/frequency control model......              TP
Documentation on generator verification...............             356               1               8           2,848     199,360 (70/hr).
                                                                    GO
Evidence Retention \46\...............................             543               1               1             543      15,204 (28/hr).
                                                             GO and TP
                                                                                -----------------------------------------------------------------

    TOTAL.............................................  ..............  ..............  ..............           7,735      467,380
--------------------------------------------------------------------------------------------------------------------------------------------------------
        TOTAL for RM13-16.............................  ..............  ..............  ..............  ..............  $3,054,296 (1,837,080 without
                                                                                one-time costs).
--------------------------------------------------------------------------------------------------------------------------------------------------------

    Title: Mandatory Reliability Standards for the Bulk-Power System
    Action: Proposed revisions to FERC-725A.
    OMB Control No: 1902-0244
    Respondents: Businesses or other for-profit institutions; not-for-
profit institutions.
    Frequency of Responses: One-time, every five years, and every ten
years.
    Necessity of the Information: The proposed approval of the five
Reliability Standards noted above implements the Congressional mandate
of the Energy Policy Act of 2005 to develop mandatory and enforceable
Reliability Standards to better ensure the reliability of the nation's
Bulk-Power System.
    Internal Review: The Commission has reviewed the proposed approval
to the Reliability Standards and made a determination that its action
is necessary to implement section 215 of the FPA. The Commission has
assured itself, by means of its internal review, that there is
specific, objective support for the burden estimate associated with the
information requirements.
    39. Interested persons may obtain information on the reporting
requirements by contacting the following: Federal Energy Regulatory
Commission, 888 First Street NE., Washington, DC 20426 [Attention:
Ellen Brown, Office of the Executive Director, email:
<EMAIL_ADDRESS>phone:<PHONE_NUMBER>, fax:<PHONE_NUMBER>].
    40. For submitting comments concerning the collection of
information and the associated burden estimates, please send your
comments to the Commission, and to the Office of Management and Budget,
Office of Information and Regulatory Affairs, Washington, DC 20503
[Attention: Desk Officer for the Federal Energy Regulatory Commission,
phone:<PHONE_NUMBER>, fax:<PHONE_NUMBER>]. For security reasons,
comments to OMB should be submitted by email to<EMAIL_ADDRESS>Comments submitted to OMB should include Docket
Number RM13-16-000 and OMB Control Number 1902-0252 and 1902-0261.

V. Regulatory Flexibility Act Certification

    41. The Regulatory Flexibility Act of 1980 (RFA) \47\ generally
requires a description and analysis of proposed rules that will have
significant economic impact on a substantial number of small entities.
The RFA mandates consideration of regulatory alternatives that
accomplish the stated objectives of a proposed rule and that minimize
any significant economic impact on a substantial number of small
entities. The Small Business Administration's (SBA's) Office of Size
Standards develops the numerical definition of a small business.\48\
The SBA has established a size standard for electric utilities, stating
that a firm is small if, including its affiliates, it is primarily
engaged in the transmission, generation and/or distribution of electric
energy for sale and its total electric output for the preceding twelve
months did not exceed four million megawatt hours.\49\
---------------------------------------------------------------------------

    \47\ 5 U.S.C. 601-612 (2006).
    \48\ 13 CFR 121.101 (2013).
    \49\ 13 CFR 121.201, Sector 22, Utilities & n.1.
---------------------------------------------------------------------------

    42. Proposed Reliability Standards MOD-025-2, MOD-026-1, MOD-027-1,
PRC-019-1 and PRC-024-1, MOD-025-2 help ensure that generators remain
in operation during specified voltage and frequency excursions,
properly coordinate protective relays and generator voltage regulator
controls, and ensure that generator models accurately reflect the
generator's capabilities and equipment performance. Comparison of the
NERC Compliance Registry with data submitted to the Energy Information
Administration on Form EIA-861 indicates that, of the 901 generator
owners in the United States registered by NERC, 49 qualify as small
entities (5.4 percent) and of the 184 of the transmission planners in
the United States registered by NERC, 42 qualify as small entities (22
percent). The Commission estimates that the small entities to whom the
proposed Reliability Standards PRC-019-1, PRC-024-1 and MOD-025-1
applies will incur compliance \50\ and record keeping costs \51\ of
$655,228 ($13,372 per generator owner). For the proposed Reliability
Standards MOD-026-1 and MOD-027-1, the Commission estimates that the
small generator owner entities (22) will incur compliance and record
keeping costs of $83,072 ($3,776 per generator owner). This will result
in a total compliance and record-keeping cost for generator owners of
$686,870 ($14,018 per entity). Additionally, small transmission planner
entities (42) will incur compliance and record keeping costs \52\ of
$47,040 ($1,120 per transmission planner).
---------------------------------------------------------------------------

    \50\ Assuming 50 hours per generator owner for relay settings/
testing based on $70/hour.
    \51\ This cost came from the above PRC-019-1, PRC-024-1, and
MOD-025-2 tables.
    \52\ This cost came from the above MOD-026-1 and MOD-027-1
tables.
---------------------------------------------------------------------------

    43. The Commission does not consider the estimated costs per small
entity to have a significant economic impact for a substantial number
of small entities. Accordingly, the Commission certifies that this
proposed rulemaking will not have a significant economic impact on a
substantial number of small entities. The Commission seeks comment on
this certification.

VI. Environmental Analysis

    44. The Commission is required to prepare an Environmental
Assessment or an Environmental Impact Statement for any action that may
have a significant adverse effect on the human environment.\53\ The
Commission has categorically excluded certain actions from this
requirement as not having a significant effect on the human
environment. Included in the exclusion are rules that are clarifying,
corrective, or procedural or that do not substantially change the
effect of the regulations being amended.\54\ The actions proposed here
fall within this categorical exclusion in the Commission's regulations.
---------------------------------------------------------------------------

    \53\ Regulations Implementing the National Environmental Policy
Act of 1969, Order No. 486, FERC Stats. & Regs., Regulations
Preambles 1986-1990 ] 30,783 (1987).
    \54\ 18 CFR 380.4(a)(2)(ii).

---------------------------------------------------------------------------

VII. Comment Procedures

    45. The Commission invites interested persons to submit comments on
the matters and issues proposed in this notice to be adopted, including
any related matters or alternative proposals that commenters may wish
to discuss. Comments are due November 25, 2013. Comments must refer to
Docket No. RM13-16-000, and must include the commenter's name, the
organization they represent, if applicable, and their address in their
comments.
    46. The Commission encourages comments to be filed electronically
via the eFiling link on the Commission's Web site at http://www.ferc.gov. The Commission accepts most standard word processing
formats. Documents created electronically using word processing
software should be filed in native applications or print-to-PDF format
and not in a scanned format. Commenters filing electronically do not
need to make a paper filing.
    47. Commenters that are not able to file comments electronically
must send original and 14 copies of their comments to: Federal Energy
Regulatory Commission, Secretary of the Commission, 888 First Street
NE., Washington, DC 20426.
    48. 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. Commenters on this proposal are
not required to serve copies of their comments on other commenters.

VIII. Document Availability

    49. 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 5:00 p.m. Eastern time) at 888 First Street NE., Room 2A,
Washington DC 20426.
    50. From the Commission's Home Page on the Internet, this
information is available on eLibrary. 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 in eLibrary, type
the docket number excluding the last three digits of this document in
the docket number field.
    51. User assistance is available for eLibrary and the Commission's
Web site during normal business hours from the Commission's Online
Support at<PHONE_NUMBER> (toll free at 1-866-208-3676) or email at
<EMAIL_ADDRESS>or the Public Reference Room at (202) 502-
8371, TTY<PHONE_NUMBER>. Email the Public Reference Room at
<EMAIL_ADDRESS>
    By the direction of the Commission.
Nathaniel J. Davis, Sr.,
Deputy Secretary.
[FR Doc. 2013-23169 Filed 9-23-13; 8:45 am]
BILLING CODE 6717-01-P