[Federal Register Volume 76, Number 184 (Thursday, September 22, 2011)]
[Rules and Regulations]
[Pages 58716-58720]
From the Federal Register Online via the Government Printing Office [www.gpo.gov]
[FR Doc No: 2011-24408]
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DEPARTMENT OF ENERGY
Federal Energy Regulatory Commission
18 CFR Part 40
[Docket No. RM10-6-000; Order No. 754]
Interpretation of Transmission Planning Reliability Standard
AGENCY: Federal Energy Regulatory Commission, Energy.
ACTION: Final rule.
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SUMMARY: On November 17, 2009, the North American Electric Reliability
Corporation (NERC) submitted a petition requesting approval of NERC's
interpretation of Requirement R1.3.10 of Commission-approved
transmission planning Reliability Standard TPL-002-0 (System
Performance Following Loss of a Single Bulk Electric System Element).
In a March 2010 Notice of Proposed Rulemaking (NOPR), the Commission
proposed to reject NERC's proposed interpretation, and instead proposed
an alternative interpretation of Requirement R1.3.10 of Reliability
Standard TPL-002-0. As a result of the comments received in response to
the proposal, the Commission declines to adopt the NOPR proposal and
approves NERC's proposed interpretation. In addition, as proposed by
several commenters, the Commission directs NERC and Commission staff to
initiate a process to identify any reliability issues, as discussed
below.
DATES: Effective Date: This rule will become effective October 24,
2011.
FOR FURTHER INFORMATION CONTACT:
Ron LeComte (Legal Information), Office of General Counsel, 888 First
Street, NE., Washington, DC 20426. ron.lecomte@ferc.gov.
Eugene Blick (Technical Information), Office of Electric Reliability,
888 First Street, NE., Washington, DC 20426. eugene.blick@ferc.gov.
Lauren Rosenblatt (Legal Information), Office of Enforcement, 888 First
Street, NE., Washington, DC 20426. lauren.rosenblatt@ferc.gov.
SUPPLEMENTARY INFORMATION: 136 FERC ] 61,186
Before Commissioners: Jon Wellinghoff, Chairman; Marc Spitzer,
Philip D. Moeller, John R. Norris, and Cheryl A. LaFleur.
Issued September 15, 2011
1. On November 17, 2009, the North American Electric Reliability
Corporation (NERC) submitted a petition requesting approval of NERC's
interpretation of Requirement R1.3.10 of Commission-approved
transmission planning Reliability Standard TPL-002-0 (System
Performance Following Loss of a Single Bulk Electric System Element).
In a March 2010 Notice of Proposed Rulemaking (NOPR),\1\ the Commission
proposed to reject NERC's proposed interpretation, and instead proposed
an alternative interpretation of Requirement R1.3.10 of Reliability
Standard TPL-002-0. As a result of the comments received in response to
the proposal, the Commission declines to adopt the NOPR proposal and
approves NERC's proposed interpretation of Requirement R1.3.10 of
Reliability Standard TPL-002-0. In addition, as proposed by several
commenters, the Commission directs NERC and Commission staff to
initiate a process to identify any reliability issues, as discussed
below.
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\1\ Interpretation of Transmission Planning Reliability
Standards, 75 FR 14386 (March 25, 2010), FERC Stats. & Regs. ]
32,655 (2010).
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I. Background
2. Section 215 of the Federal Power Act (FPA) requires a
Commission-certified Electric Reliability Organization (ERO) to develop
mandatory and enforceable Reliability Standards, which are subject to
Commission review and approval.\2\ Specifically, the Commission may
approve, by rule or order, a proposed Reliability Standard or
modification to a Reliability Standard if it determines that the
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\
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\2\ 16 U.S.C. 824 (2006).
\3\ Id. 824o(d)(2).
\4\ Id. 824o(e)(3).
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[[Page 58717]]
3. 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 April 4, 2006, NERC submitted to the Commission a petition
seeking approval of 107 proposed Reliability Standards. On March 16,
2007, the Commission issued a final rule, Order No. 693,\7\ approving
83 of the 107 Reliability Standards, including transmission planning
Reliability Standards TPL-001-0 through TPL-004-0. In addition,
pursuant to section 215(d)(5) of the FPA,\8\ the Commission directed
NERC to develop modifications to 56 of the 83 approved Reliability
Standards, including TPL-002-0.\9\
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\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 & compliance, 117 FERC ] 61,126 (2006), aff'd
sub nom. Alcoa, Inc. v. FERC, 564 F.3d 1342 (DC Cir. 2009).
\7\ 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).
\8\ 16 U.S.C. 824o(d)(5).
\9\ Order No. 693, FERC Stats & Regs. ] 31,242 at P 1797.
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4. NERC's Rules of Procedure provide that a person that is
``directly and materially affected'' by Bulk-Power System reliability
may request an interpretation of a Reliability Standard.\10\ In
response, the ERO will assemble a team with relevant expertise to
address the requested interpretation and also form a ballot pool.
NERC's Rules of Procedure provide that, within 45 days, the team will
draft an interpretation of the reliability standard and submit it to
the ballot pool. If approved by the ballot pool and subsequently by the
NERC Board of Trustees, the interpretation is appended to the
Reliability Standard and filed with the applicable regulatory
authorities for approval.
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\10\ NERC Rules of Procedure, Appendix 3A, Reliability Standards
Development Procedure, Version 6.1, at 27-29 (2010).
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II. Transmission Planning Reliability Standards
5. Each of the TPL Reliability Standards, TPL-001-0 through TPL-
004-0, requires the planning authorities and transmission planners
(planner) to provide a ``valid assessment'' that would ``ensure that
reliable systems are developed that meet specified performance
requirements'' both in the near-term (years one through five) and in
the longer-term (years six through ten, or as needed). For each of
these TPL Reliability Standards, entities must adequately assess a
range of operating conditions on their systems and plan to meet certain
performance criteria that the TPL Reliability Standards specify for
each of four classes of contingencies.\11\ The principles that planners
must apply to the design of the assessment and of the supporting
studies are set forth in the Requirements of the specific TPL
Reliability Standard.
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\11\ Reliability Standards TPL-001-0 through TPL-004-0 each
includes the same Table I, titled ``Transmission System Standards--
Normal and Emergency Conditions,'' which identifies the classes of
contingencies as Category A through Category D. Reliability Standard
TPL-002-0 addresses Category B contingencies.
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6. Table I, which is incorporated into each of the TPL Reliability
Standards, sets forth the different types of contingencies that
planners must study in conjunction with critical system conditions. The
performance that must be met before and after experiencing those
contingencies is also defined in the Table I, including reliably
meeting all projected customer demand and firm transfers for Category B
contingencies.
7. Requirement R1 of Reliability Standard TPL-002-0 states:
R1. The Planning Authority and Transmission Planner shall each
demonstrate through a valid assessment that its portion of the
interconnected transmission system is planned such that the Network
can be operated to supply projected customer demands and projected
Firm (non-recallable reserved) Transmission Services, at all demand
levels over the range of forecast system demands, under the
contingency conditions as defined in Category B.[\12\] To be valid,
the Planning Authority and Transmission Planner assessments shall: *
* *.
\12\ Category B contingencies are defined in Table I of the
Reliability Standard.
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8. Requirement R1 proceeds with sub-Requirements R1.1 through R1.5,
which provide the criteria that must be met to qualify the assessment
directed by Requirement R1 as valid. In particular, Requirement R1.3
mandates that the assessment shall
[b]e supported by a current or past study and/or system
simulation testing that addresses each of the following categories,
showing system performance following Category B. The specific
elements selected (from each of the following categories) for
inclusion in these studies and simulations shall be acceptable to
the associated Regional Reliability Organization(s).
Further, Requirement R1.3.10 requires the planner to
[i]nclude the effects of existing and planned protection
systems, including any backup or redundant systems.
III. NERC Proposed Interpretation
9. In the NERC Petition, NERC explained that it received a request
from PacifiCorp for an interpretation of Reliability Standard TPL-002-
0, Requirement R1.3.10, addressing three specific questions. The
PacifiCorp questions and NERC interpretations were as follows:
Question 1: Does TPL-002-0 R1.3.10 require that all elements
that are expected to be removed from service through normal
operation of the protection systems be removed in simulations?
Response 1: TPL-002-0 requires that System studies or
simulations be made to assess the impact of single Contingency
operation with Normal Clearing. TPL-002-0, R1.3.10 does require that
all elements expected to be removed from service through normal
operations of the Protection Systems be removed in simulations.
Question 2: Is a Category B disturbance limited to faults with
[N]ormal [C]learing where the protection system operates as designed
in the time expected with proper functioning of the protection
system(s) or do Category B disturbances extend to protection system
misoperations and failures?
Response 2: This standard does not require an assessment of the
Transmission System performance due to a Protection System failure
or Protection System misoperation. Protection System failure or
Protection System misoperation is addressed in TPL-003-0--System
Performance following Loss of Two or More Bulk Electric System
Elements (Category C) and TPL-004-0--System Performance Following
Extreme Events Resulting in the Loss of Two or More Bulk Electric
System (BES) Elements (Category D).
Question 3: Does TPL-002-0, R1.3.10 require that planning for
Category B [C]ontingencies assume a [C]ontingency that results in
something other than a [N]ormal [C]learing event even though the
TPL-002-0 Table I--Category B matrix uses the phrase ``SLG or 3-
Phase Fault, with Normal Clearing?''
Response 3: TPL-002-0, R1.3.10 does not require simulating
anything other than Normal Clearing when assessing the impact of a
Single Line Ground (SLG) or 3-Phase (3[Oslash]) Fault on the
performance of the Transmission System.\13\
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\13\ NERC Petition at 10. In support for its request for an
interpretation, PacifiCorp states that ``[i]f TPL-002-0, R1.3.10
requires that planning for Category B Contingencies must assume
failure or misoperation of all existing and planned protection
systems, protection system failures previously identified as
Category C [[Oslash]] Contingencies or Category D [[Oslash]]
Contingencies would now become Category B Contingencies * * *.'' Id.
at Appendix A at 1-2.
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10. In support of its request for approval, NERC stated that the
proposed interpretation directly supports the reliability purpose of
TPL-002-0 because it clarifies what is required for the ``System
simulations'' cited in the main requirement without expanding
[[Page 58718]]
the reach of the standard.\14\ NERC maintained that the proposed
interpretation clearly identifies what needs to be done--that all
elements expected to be removed from service through normal operation
of the protection system must be removed in simulations and that only
normal clearing is required in the simulations. NERC stated that the
proposed interpretation clearly distinguishes that misoperations and
failures of the protection system are not part of Reliability Standard
TPL-002-0, but are addressed in other standards. NERC stated that the
interpretation will result in ensuring that an adequate level of
reliability for the Bulk-Power System will be achieved and maintained
by providing clarity and certainty in support of the objective.
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\14\ Id. at 11.
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IV. Commission NOPR
11. The Commission proposed to reject NERC's proposed
interpretation and proposed an alternative interpretation. The
Commission's proposed interpretation would have required modeling of
the non-operation of non-redundant primary protection systems to be in
compliance with Requirement R1.3.10 of Reliability Standard TPL-002-0.
In the NOPR, the Commission stated that a planner would perform an
assessment of its portion of the interconnected transmission system
through computer modeling and simulations, in which the planner first
creates base cases. Using these base cases as a starting point, the
planner then assesses the performance of the system and tests the base
cases by subjecting them to various Category B Contingencies outlined
in Table I with normal clearing. The Commission's proposed
interpretation would have found that Requirement R1.3.10 of TPL-002-0
requires planners to study, in their system assessments, the non-
operation of non-redundant primary protection systems in order to
ascertain whether and how reliance on the as-designed backup or
redundant protection systems affects reliability.\15\
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\15\ Interpretation of Transmission Planning Reliability
Standards, FERC Stats. & Regs. ] 32,655, at P 15 (2010).
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12. The Commission proposed that its interpretation of R1.3.10 of
Reliability Standard TPL-002-0 would apply prospectively from the
effective date of any Final Rule and no entity will be subject to
financial penalties for having operated in a manner inconsistent with
this proposed interpretation prior to the effective date of any Final
Rule.
V. Comments
13. Twenty-seven entities provided comments on the Commission's
proposed interpretation.\16\ Almost uniformly, comments support NERC's
proposed interpretation.\17\ In general, commenters \18\ state that the
non-operation of a primary protection system is not studied under TPL-
002-0, but rather under TPL-003-0 and TPL-004-0 as an unplanned event
with delayed clearing.\19\ Commenters contend that only planned
protection system outages (maintenance outages) should be addressed
under TPL-002-0.\20\ In addition, commenters assert that the
Commission's interpretation would require the installation of fully
redundant protection systems at an estimated cost of $24 billion and
require significant construction efforts spanning 10 to 20 years.\21\
Commenters contend that TPL-002-0 relates to Normal Clearing and not
Delayed Clearing in which a protection system failure has occurred or
fails to operate.
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\16\ A list of commenters is provided in Appendix 1.
\17\ Commenters including NERC, Trade Associations (Edison
Electric Institute, American Public Power Association, National
Rural Electric Cooperative Association, Electric Power Supply
Association, Transmission Access Policy Study Group, and Canadian
Electricity Association), Florida Reliability Coordinating Council
and others indicate support for NERC's interpretation of Requirement
R1.3.10 of TPL-002-0. In contrast, the International Transmission
Companies (ITC) commented that the Commission's proposal
``establishes an additional level of good utility practice'' and
``is a reasonable and rational approach to evaluate system
consequences, under Requirement R1.3.10 of TPL-002-0, regarding
element outages and clearing times associated with non-operation of
the primary protection system.'' However, given the corrective
actions that would be required to comply with the Commission's
proposal, ITC requests that the Commission allow an appropriate
amount of time for compliance.
\18\ See, e.g., NERC comments at 7-8; Trade Association Comments
at 19-23.
\19\ Planned outages are modeled as one of the base case
conditions (categories) and studied to achieve the performance
requirements of Category B (single contingencies), Table I.
Protection system failures are addressed by performance requirements
of Category C (two or more contingencies) and misoperations are
addressed by Category D (extreme events).
\20\ Requirement R.1.3.12 of TPL-002-0 requires the planner to
consider the planned (including maintenance) outage of protection
systems at demand levels for which such outages are performed.
\21\ See Trade Associations comments at 31-34.
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14. NERC explains that the pre-2007 voluntary transmission planning
standard was broken into four mandatory Version 0 Standards linked by
the performance categories of Table I. Thus, according to NERC, some
continuity was lost and, as a result, sub-requirements such as
Requirement R1.3.10 that appear in TPL-002-0 through TPL-004-0 have
very limited applicability in the context of TPL-002-0. NERC explains
that Requirement R1.3.10 of TPL-002-0 is a valid requirement for
judging system performance, but only in those cases where the system is
being studied to determine its ability to perform when a given primary
protection system or one of its components is out of service for
maintenance (Requirement R1.3.12).
A. Supplemental Comments
15. The Trade Associations submitted supplemental comments, with
additional comments in support filed by NERC. The Trade Associations
reiterate their request that the Commission approve, without change,
NERC's proposed interpretation of Reliability Standard TPL-002-0
Requirement R1.3.10. The Trade Associations also state that, based on
outreach meetings with Commission staff, there may be a system
protection issue that merits further exploration by technical experts.
Thus, the Trade Associations suggest that the Commission take the
following two actions. First, instruct Commission Reliability Staff to
meet with NERC and its appropriate subject matter experts to: (a)
Explore Staff's concerns and identify whether there is a further system
protection issue warranting additional actions, and (b) if so, define
the issue's scope and assess its importance. The Trade Associations
state such exchange of views among technical experts would be intended
to facilitate the subject matter experts' ability to recommend
appropriate actions within NERC. Second, direct NERC to submit an
informational filing within six months to explain its view as to
whether there is a further system protection issue that needs to be
addressed and if so, what forum and process should be used to address
that issue and what priority it should be accorded relative to other
reliability initiatives planned by NERC.\22\
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\22\ Trade Associations Supplemental Comments at 3 (footnote
omitted).
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16. NERC supports the Trade Associations' proposal to give NERC,
Commission staff, and technical experts the opportunity to further
examine whether there may be a potential system protection issue that
needs to be addressed. NERC states that it would make an informational
filing with the Commission regarding whether there is a further system
protection issue that needs to be addressed and if so, what forum and
process should be used to address that issue and what priority it
should be accorded relative to other reliability initiatives planned by
NERC.
[[Page 58719]]
17. NERC requests that the Commission approve the proposed
interpretation of Reliability Standard TPL-002-0 Requirement R1.3.10,
as filed.
VI. Discussion
18. In the NOPR, the Commission proposed to find that Reliability
Standard TPL-002-0, Requirement R1.3.10 requires the study of the non-
operation of non-redundant primary protection systems. Based on the
comments received, the Commission accepts NERC's interpretation of TPL-
002-0, Requirement R1.3.10, that finds that the requirement does not
require the study of non-operation of non-redundant primary protection
systems. Because we find NERC's proposed interpretation to be just and
reasonable, we, therefore, decline to adopt the NOPR proposal.
19. We agree with the Trade Associations that there may be a system
protection issue that merits further exploration by technical experts.
The comments received in response to the Commission's NOPR and
Commission staff outreach discussions indicate that there may have been
a misunderstanding that the Commission's proposed interpretation would
have established a full redundancy requirement for all primary
protection systems. The Commission clarifies that it did not intend to
require full redundancy. Rather, the Commission believes that there is
an issue concerning the study of the non-operation of non-redundant
primary protection systems; e.g., the study of a single point of
failure on protection systems. The Commission agrees with commenters
that this issue does not have to be addressed in TPL-002-0, Requirement
R1.3.10.
20. Accordingly, consistent with the supplemental comments of the
Trade Associations, we direct Commission staff to meet with NERC and
its appropriate subject matter experts to explore this reliability
concern, including where it can best be addressed, and identify any
additional actions necessary to address the matter. Further, we direct
NERC to make an informational filing within six months of the date of
the issuance of this Final Rule explaining whether there is a further
system protection issue that needs to be addressed and, if so, what
forum and process should be used to address that issue and what
priority it should be accorded relative to other reliability
initiatives planned by NERC.\23\
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\23\ This filing requirement has been approved by the Office of
Management and Budget under FERC-725, OMB Control No. 1902-0225.
This filing does not change the existing burden or reporting
requirements imposed on NERC under FERC-725.
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VII. Information Collection Statement
21. The Office of Management and Budget (OMB) regulations require
that OMB approve certain reporting and recordkeeping (collections of
information) imposed by an agency.\24\ The information contained here
is also subject to review under section 3507(d) of the Paperwork
Reduction Act of 1995.\25\
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\24\ 5 CFR 1320.11.
\25\ 44 U.S.C. 3507(d).
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22. As stated above, the Commission previously approved, in Order
No. 693, the Reliability Standard that is the subject of the current
Final Rule. This Final Rule accepts an interpretation of the currently
approved Reliability Standard and does not change this standard. The
interpretation of the current Reliability Standard at issue in this
final rule is not expected to change the reporting burden or the
information collection requirements. The informational filing required
of NERC is part of currently active collection FERC-725 and does not
require additional approval by OMB.\26\
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\26\ See supra n. 23.
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23. We will submit this final rule to OMB for informational
purposes only.
24. 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, e-mail:
data.clearance@ferc.gov, phone: (202) 502-8663, or fax: (202) 273-
0873].
VIII. Environmental Analysis
25. 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.\27\ 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.\28\ The actions proposed
herein fall within this categorical exclusion in the Commission's
regulations.
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\27\ Regulations Implementing the National Environmental Policy
Act of 1969, Order No. 486, FERC Stats. & Regs. ] 30,783 (1987).
\28\ 18 CFR 380.4(a)(2)(ii).
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IX. Regulatory Flexibility Act
26. The Regulatory Flexibility Act of 1980 (RFA) \29\ generally
requires a description and analysis of final 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) Office of Size
Standards develops the numerical definition of a small business.\30\
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.\31\ The RFA is not
implicated by this Final Rule because the interpretation accepted
herein does not modify the existing burden or reporting requirements.
With no changes to the Reliability Standard as approved, the Commission
certifies that this Final Rule will not have a significant economic
impact on a substantial number of small entities.
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\29\ 5 U.S.C. 601-612.
\30\ 13 CFR 121.201.
\31\ Id. n. 1.
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X. Document Availability
27. 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 FERC's Home Page (http://www.ferc.gov) and in FERC's
Public Reference Room during normal business hours (8:30 a.m. to 5 p.m.
Eastern time) at 888 First Street, NE., Room 2A, Washington DC 20426.
28. From FERC'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.
29. User assistance is available for eLibrary and the FERC's Web
site during normal business hours from FERC Online Support at (202)
502-6652 (toll free at 1-866-208-3676) or e-mail at
[[Page 58720]]
ferconlinesupport@ferc.gov, or the Public Reference Room at (202) 502-
8371, TTY (202) 502-8659. E-mail the Public Reference Room at
public.referenceroom@ferc.gov.
XI. Effective Date and Congressional Notification
30. This final rule is effective 30 days from publication in
Federal Register. The Commission has determined, with the concurrence
of the Administrator of the Office of Information and Regulatory
Affairs of OMB that this rule is not a ``major rule'' as defined in
section 351 of the Small Business Regulatory Enforcement Fairness Act
of 1996.
List of Subjects in 18 CFR Part 40
Applicability, Mandatory reliability standards.
By the Commission.
Kimberly D. Bose,
Secretary.
Note: The following appendix will not appear in the Code of
Federal Regulations.
Appendix 1
List of Commenters
American Transmission Company LLC
Avista Corporation
Black Hills Power, Inc.
Bonneville Power Administration
Constellation Energy Group, Inc.\32\
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\32\ Baltimore Gas & Electric Company, Constellation Energy
Commodities Group, Inc., Constellation Energy Control and Dispatch,
LLC, Constellation NewEnergy, Inc., and Constellation Power Source
Generation, Inc., and Constellation Energy Nuclear Group, LLC.
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Department of Interior, Office of Environmental Policy and
Compliance
Entergy Services, Inc.
Exelon Corporation
Florida Reliability Coordinating Council
Independent Electricity System Operator and Hydro One Networks
International Transmission Company \33\
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\33\ ITCTransmission, Michigan Electric Transmission Company,
LLC, ITC Midwest LLC, and ITC Great Plains, LLC.
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ISO/RTO Council
Kansas City Power & Light Company, KCP&L Greater Missouri Operations
Company
Manitoba Hydro
Modesto Irrigation District
National Grid
New England States Committee on Electricity
North American Electric Reliability Corporation
Pacific Gas and Electric Company
Public Power Council \34\
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\34\ Public Power Council includes Washington Rural Electric
Cooperative Association, Idaho Consumer-Owned Utilities Association,
Oregon PUD Association, Northwest Public Power Association, Oregon
Rural Electric Cooperative Association, PNGC Power, Western Public
Agencies Group, Western Montana Electric G&T Cooperative, Inc.,
Oregon Municipal Electric Utilities Association, Washington PUD
Association, Northwest Requirements Utilities.
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Reliability First Corporation
San Diego Gas & Electric Company
Southern Company Services, Inc.\35\
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\35\ Alabama Power Company, Georgia Power Company, Gulf Power
Company, and Mississippi Power Company.
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Trade Associations \36\
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\36\ The Trade Association includes the Edison Electric
Institute, the American Public Power Association, Canadian
Electricity Association, the National Rural Electric Cooperative
Association, the Transmission Access Policy Study Group, and the
Electric Power Supply Association.
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Tampa Electric Company
Virginia Electric and Power Company, doing business as Dominion
Virginia Power
Wisconsin Electric Power Company
[FR Doc. 2011-24408 Filed 9-21-11; 8:45 am]
BILLING CODE 6717-01-P