
[Federal Register: November 24, 2010 (Volume 75, Number 226)]
[Proposed Rules]               
[Page 71613-71625]
From the Federal Register Online via GPO Access [wais.access.gpo.gov]
[DOCID:fr24no10-42]                         

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DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

18 CFR Part 40

[Docket No. RM10-15-000]

 
Mandatory Reliability Standards for Interconnection Reliability 
Operating Limits

November 18, 2010.
AGENCY: Federal Energy Regulatory Commission.

ACTION: Notice of proposed rulemaking.

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SUMMARY: Under section 215 of the Federal Power Act, the Federal Energy 
Regulatory Commission proposes to approve three new Interconnection 
Reliability Operations and Coordination Reliability Standards and seven 
revised Reliability Standards related to Emergency Preparedness and 
Operations, Interconnection Reliability Operations and Coordination, 
and Transmission Operations. These proposed Reliability Standards were 
submitted to the Commission for approval by the North American Electric 
Reliability Corporation, which the Commission has certified as the 
Electric Reliability Organization responsible for developing and 
enforcing mandatory Reliability Standards. The proposed Reliability 
Standards were designed to prevent instability, uncontrolled 
separation, or cascading outages that adversely impact the reliability 
of the interconnection by ensuring prompt action to prevent or mitigate 
instances of exceeding Interconnection Reliability Operating Limits. 
The Commission also proposes to approve the addition of two new terms 
to the NERC Glossary of Terms. In addition, pursuant to section 
215(d)(5) of the Federal Power Act, the Commission proposes to direct 
NERC to develop a modification to the proposed term ``Real-time 
Assessment'' to address a specific concern identified by the 
Commission. The Commission raises some concerns with regard to certain 
aspects of NERC's proposals and, based on the responses from NERC and 
industry, may choose to direct certain modifications to the proposed 
new and revised Reliability Standard, as well as the new Glossary 
Terms, as discussed below.

DATES: Comments are due January 24, 2011.

ADDRESSES: You may submit comments, identified by docket number and in 
accordance with the requirements posted on the Commission's Web site, 
http://www.ferc.gov. Comments may be submitted by any of the following 
methods:
     Agency Web site: Documents created electronically using 
word processing software should be filed in native applications or 
print-to-PDF format, and not in a scanned format, at http://
www.ferc.gov/docs-filing/efiling.asp.
     Mail/Hand Delivery: Commenters unable to file comments 
electronically must mail or hand-deliver an original copy of their 
comments to: Federal Energy Regulatory Commission, Secretary of the 
Commission, 888 First Street, NE., Washington, DC 20426. These 
requirements can be found on the Commission's Web site, see, e.g., the 
``Quick Reference Guide for Paper Submissions,'' available at
    http://www.ferc.gov/docs-filing/efiling.asp or via phone from FERC 
Online Support at (202) 502-6652 or toll-free at 1-866-208-3676.

FOR FURTHER INFORMATION CONTACT: 

Darrell Piatt (Technical Information), Office of Electric Reliability, 
Division of Reliability Standards, Federal Energy Regulatory 
Commission, 888 First Street, NE., Washington, DC 20426, Telephone: 
(202) 502-6687;
A. Cory Lankford (Legal Information), Office of the General Counsel, 
Federal Energy Regulatory Commission, 888 First Street, NE. Washington, 
DC 20426, Telephone: (202) 502-6711;
William Edwards (Legal Information), Office of the General Counsel, 
Federal

[[Page 71614]]

Energy Regulatory Commission, 888 First Street, NE., Washington, DC 
20426, Telephone: (202) 502-6669.

SUPPLEMENTARY INFORMATION: 

Table of Contents


                                                               Paragraph
                                                                numbers

I. Background...............................................           3
    A. Mandatory Reliability Standards......................           3
    B. Order No. 693 Directives.............................           4
II. Discussion..............................................           7
    A. System Operating Limits..............................          10
    B. Proposed New Reliability Standards...................          22
        1. IRO-008-1........................................          22
        2. IRO-009-1........................................          30
        3. IRO-010-1a.......................................          33
    C. Proposed Revised Reliability Standards...............          38
        1. EOP-001-1........................................          38
        2. IRO-002-2........................................          42
        3. IRO-004-2........................................          47
        4. IRO-005-3........................................          54
        5. TOP-003-1........................................          58
        6. TOP-005-2........................................          61
        7. TOP-006-2........................................          66
    D. Violation Severity Levels and Violation Risk Factors.          69
III. Information Collection Statement.......................          77
IV. Environmental Analysis..................................          82
V. Regulatory Flexibility Act Certification.................          83
VI. Comment Procedures......................................          84
VII. Document Availability..................................          88


Notice of Proposed Rulemaking

    1. Under section 215 of the Federal Power Act (FPA),\1\ the Federal 
Energy Regulatory Commission (Commission) proposes to approve three new 
Interconnection Reliability Operations and Coordination (IRO) 
Reliability Standards and seven revised Reliability Standards related 
to Emergency Preparedness and Operations (EOP), IRO, and Transmission 
Operations (TOP). The proposed Reliability Standards were submitted to 
the Commission for approval by the North American Electric Reliability 
Corporation (NERC), which the Commission has certified as the Electric 
Reliability Organization (ERO) responsible for developing and enforcing 
mandatory Reliability Standards.\2\ The proposed Reliability Standards 
were designed to prevent instability, uncontrolled separation, or 
cascading outages that adversely impact the reliability of the 
interconnection by ensuring prompt action to prevent or mitigate 
instances of exceeding interconnection reliability operating limits 
(IROL). The Commission also proposes to approve the addition of two new 
terms to the NERC Glossary of Terms (NERC Glossary). In addition, 
pursuant to section 215(d)(5) of the Federal Power Act, the Commission 
proposes to direct NERC to develop a modification to the proposed term 
``Real-time Assessment'' to address a specific concern identified by 
the Commission. The Commission raises some concerns with regard to 
certain aspects of these proposals and, based on the responses from 
NERC and from industry, may choose to direct certain modifications to 
the proposed new and revised Reliability Standard, as well as the new 
Glossary Terms, as discussed below.
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    \1\ 16 U.S.C. 824o.
    \2\ 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).
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    2. The three new Reliability Standards proposed by NERC are 
designated as IRO-008-1 (Reliability Coordinator Operational Analyses 
and Real-time Assessments), IRO-009-1 (Reliability Coordinator Actions 
to Operate Within IROLs), and IRO-010-1a \3\ (Reliability Coordinator 
Data Specification and Collection). In preparing these new Reliability 
Standards, the standards drafting team determined that it was necessary 
to retire or modify certain requirements from several existing 
standards. Accordingly, NERC requests Commission approval of revised 
Reliability Standards EOP-001-2,\4\ IRO-002-2, IRO-004-2, IRO-005-3, 
and TOP-006-2. NERC also proposes to add the following new terms to the 
NERC Glossary: ``Operational Planning Analysis'' and ``Real-time 
Assessment.'' \5\
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    \3\ NERC designates the version number of a Reliability Standard 
as the last digit of the Reliability Standard number. Therefore, 
original Reliability Standards end with ``-0'' and modified version 
one Reliability Standards end with ``-1.'' The NERC Board of 
Trustees approved the proposed IRO-010-1 Reliability Standard on 
October 17, 2008. Subsequently, on August 5, 2009, the NERC Board of 
Trustees approved an interpretation to the proposed IRO-010-1 
standard. Accordingly, NERC is requesting approval of both the 
proposed standard and the appended interpretation, and NERC has 
designated the proposed standard and appended interpretation as IRO-
010-1a.
    \4\ Concurrent with its filing in this Docket, NERC filed a 
petition in Docket No. RM10-16-000 seeking approval of certain 
Emergency Preparedness and Operations Reliability Standards. NERC, 
Petition for Approval of Three Emergency Preparedness and Operations 
Reliability Standards, Docket No. RM10-16-000 (filed Dec. 31, 2009). 
As part of its filing in RM10-16-000, NERC proposed to retire 
Requirement R3.4 of EOP-001-0. Each petition proposes unique changes 
to EOP-001-0 reflecting the distinct issues addressed by the 
respective Reliability Standards drafting teams. NERC indicated in 
both petitions that it could not anticipate the sequence in which 
the Commission would act and therefore included two sets of proposed 
amendments to EOP-001-0 in each petition. The Commission will 
clarify upon issuance of Final Rules in each proceeding which 
revised version of EOP-001-0 it is addressing in its determination.
    \5\ The proposed new Reliability Standards and other modified 
Reliability Standards are not codified in the CFR and are not 
attached to the NOPR. They are, however, available on the 
Commission's eLibrary document retrieval system in Docket No. RM10-
15-000 and are available on the ERO's Web site, http://www.nerc.com.
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I. Background

A. Mandatory Reliability Standards

    3. Section 215 of the FPA requires a Commission-certified ERO to 
develop mandatory and enforceable Reliability Standards, which are 
subject to Commission review and approval. Once approved, the 
Reliability Standards are

[[Page 71615]]

enforced by the ERO, subject to Commission oversight, or by the 
Commission independently.

B. Order No. 693 Directives

    4. On March 16, 2007, the Commission issued Order No. 693, 
approving 83 of the 107 initial Reliability Standards filed by NERC, 
including the existing IRO Reliability Standards.\6\ Under section 
215(d)(5) of the FPA, the Commission directed NERC to develop 
modifications to the IRO Reliability Standards to address certain 
issues identified by the Commission.
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    \6\ Mandatory Reliability Standards for the Bulk-Power System, 
Order No. 693, 72 FR 16416 (Apr. 4, 2007), FERC Stats. & Regs. ] 
31,242, order on reh'g, Order No. 693-A, 120 FERC ] 61,053 (2007).
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    5. With respect to IRO-001-1, the Commission directed the ERO to 
develop modifications to eliminate the regional reliability 
organization as an applicable entity.\7\ The Commission also directed 
the ERO to modify IRO-002-1 to require a minimum set of capabilities 
that must be made available to the reliability coordinator to ensure 
that a reliability coordinator has the capabilities it needs to perform 
its functions.\8\ With respect to IRO-003-2, the Commission directed 
the ERO to develop a modification to create criteria to define the term 
``critical facilities'' in a reliability coordinator's area and its 
adjacent systems.\9\ The Commission also directed the ERO to modify 
IRO-004-1 to require the next-day analysis to identify control actions 
that can be implemented and effective within 30 minutes after a 
contingency. In addition, the Commission directed the ERO to consider 
adding Measures and Levels of Non-Compliance to Reliability Standards 
IRO-004-1 and IRO-005-1 that are commensurate with the magnitude, 
duration, frequency and causes of the violations and whether these 
occur during normal or contingency conditions.\10\
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    \7\ Order No. 693, FERC Stats. & Regs. ] 31,242 at P 896.
    \8\ Id. P 908.
    \9\ Id. P 914.
    \10\ Id. P 935. NERC has subsequently replaced Levels of Non-
Compliance with Violation Severity Levels. See Order on Violation 
Severity Levels Proposed by the Electric Reliability Organization, 
123 FERC ] 61,284 (Violation Severity Level Order), order on reh'g, 
125 FERC ] 61,212 (2008).
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    6. The Commission also directed the ERO to conduct a survey on IROL 
practices and actual operating experiences by requiring reliability 
coordinators to report any violations of IROLs, their causes, the date 
and time, the durations and magnitudes in which actual operations 
exceed IROLs to the ERO on a monthly basis for one year beginning two 
months after the effective date of Order No. 693.\11\ On October 31, 
2008, NERC filed the results of its year-long survey with the 
Commission.\12\ On February 8, 2009, NERC supplemented those results in 
a second filing.\13\
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    \11\ Id. P 951.
    \12\ NERC, Compliance Filing, Docket No. RM06-16-006 (filed Oct. 
31, 2008).
    \13\ NERC, Compliance Filing, Docket No. RM06-16-006 (filed Feb. 
8, 2009).
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II. Discussion

    7. In a December 31, 2009 filing (NERC Petition),\14\ NERC requests 
Commission approval of proposed Reliability Standards IRO-008-1, IRO-
009-1, and IRO-010-1a. NERC contends that these new Reliability 
Standards would address certain Commission directives from Order No. 
693. In developing the new IRO Reliability Standards, NERC determined 
that it was necessary to retire or modify certain requirements from 
several existing standards. Accordingly, NERC proposes revised 
Reliability Standards EOP-001-1, IRO-002-2, IRO-004-2, IRO-005-3, TOP-
003-1, TOP-005-2, and TOP-006-2. NERC also requests approval of new 
definitions ``Operational Planning Analysis'' and ``Real-time 
Assessment.''
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    \14\ North American Electric Reliability Corp., Dec. 31, 2009 
Petition for Approval of Proposed New and Revised Reliability 
Standards for Operating Within Interconnection Operating Limits 
(NERC Petition).
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    8. As discussed below, the Commission proposes to approve new 
Reliability Standards IRO-008-1, IRO-009-1, and IRO-010-1a. The 
Commission also proposes to approve revised Reliability Standards EOP-
001-1, IRO-002-2, IRO-004-2, IRO-005-3, TOP-003-1, TOP-005-2, and TOP-
006-2 as well as the two new NERC Glossary terms.
    9. In addition, the Commission seeks comment on specific concerns 
related to the proposed IRO Reliability Standards, as set forth below.

A. System Operating Limits

    10. To maintain the reliable operation of the Bulk-Power System, 
reliability coordinators, balancing authorities, and transmission 
operators must be aware of the applicable system operating limits 
(SOLs) and interconnection reliability operating limits (IROLs) on 
their system. NERC defines SOLs as the value (such as MW, MVar, 
Amperes, Frequency or Volts) that satisfies the most limiting of the 
prescribed operating criteria for a specific system configuration to 
ensure operation within acceptable reliability criteria. These SOLs are 
based upon certain operating criteria. IROLs are, essentially, a subset 
of SOLs. NERC defines IROLs as the value (such as MW, MVar, Amperes, 
Frequency or Volts) derived from, or a subset of the SOLs, which if 
exceeded, could expose a widespread area of the bulk electric system to 
instability, uncontrolled separation, or cascading outages.\15\
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    \15\ See NERC Glossary, available at http://www.nerc.com/docs/
standards/rs/Glossary_of_Terms_2010April20.pdf.
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NERC Proposal
    11. The proposed IRO Reliability Standards together with the 
proposed revisions to existing Reliability Standards would divide 
responsibility for SOLs and IROLs between reliability coordinators and 
transmission operators according to the Functional Model.\16\ NERC 
explains that having two entities with the same primary responsibility 
is not supported by the Functional Model. However, NERC notes that the 
proposed Reliability Standards should not imply that the reliability 
coordinator will not look at its future operations with respect to 
specific SOLs.\17\ NERC states that the reliability coordinator must 
look at its future operations with respect to specific SOLs to ensure 
that their transmission operators are taking actions at appropriate 
times, but the primary responsibility for SOLs rests with the 
transmission operators. NERC explains that, under the proposed 
Reliability Standards, the reliability coordinator retains overall 
visibility of all operations within its Wide-Area view, including some 
SOLs, although the transmission operator is primarily responsible for 
actions related to SOLs.\18\ NERC states that the IRO standards were 
developed in support of the authority and assignment of tasks in the 
Functional Model.\19\ NERC explains that under the Functional Model, 
while reliability coordinators will assign their transmission operators 
tasks associated with IROLs, the reliability coordinator has ultimate 
responsibility for these tasks, and the reliability coordinator is 
sanctioned if these tasks are not performed as required by the 
Reliability Standards.\20\
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    \16\ NERC, Reliability Functional Model, version 5, at 30 (Nov. 
2009), available at http://www.nerc.com/files/Functional_Model_
V5_Final_2009Dec1.pdf.
    \17\ NERC Petition at 77.
    \18\ Id. at 78.
    \19\ Id. at 7-9.
    \20\ Id. at 8.
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    12. NERC explains that, under the Functional Model, the reliability 
coordinator is the functional entity with the highest level of 
responsibility and authority for real-time reliability of the Bulk-
Power System. NERC states that the reliability coordinator is 
responsible

[[Page 71616]]

for identifying the subset of SOLs that are known as IROLs, and may 
direct its transmission operators to take actions associated with 
IROLs. In assigning a single task to a single functional entity, under 
the Functional Model, the reliability coordinator is the sole 
functional entity responsible for developing IROLs and for actions to 
prevent/mitigate instances of exceeding IROLs. While the transmission 
operator has no ``direct'' responsibility for developing IROLs, the 
transmission operator may be assigned the task of developing some 
IROLs, monitoring real-time values against identified IROLs, and taking 
actions to prevent reaching an IROL or to mitigate an instance of 
exceeding an IROL. However, the transmission operator only performs 
these tasks when directed to do so by its reliability coordinator.\21\
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    \21\ Id.
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    13. NERC further explains that, in a similar fashion, the 
Functional Model assigns responsibility for SOLs that are not IROLs to 
the transmission operator. But, NERC states, this too is a shared 
responsibility.\22\ NERC states that where the Transmission Operator 
has primary responsibility for developing the SOLs within its 
transmission operator area, the transmission operator may request the 
assistance of its reliability coordinator in developing these SOLs. In 
addition, NERC states that it is the reliability coordinator that is 
held responsible for ensuring that transmission operators develop SOLs 
for its reliability coordinator area in accordance with a methodology 
developed by the reliability coordinator. NERC states that the 
transmission operator must share its SOLs with its reliability 
coordinator, and the reliability coordinator must share any SOLs it 
develops with its transmission operator. NERC also states that the 
reliability coordinator monitors the status of some, but not all, SOLs.
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    \22\ Id. at 9.
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    14. According to NERC, the reliability coordinator's visualization 
capabilities are not expected to display all SOLs within the Wide-Area 
that the reliability coordinator monitors because this would mix SOLs 
that have little impact on reliability with those SOLs that are 
associated with facilities that are important to the Bulk-Power System. 
NERC states that the reliability coordinator's visualization 
capabilities are expected to display the real-time status of parameters 
against all IROLs that the reliability coordinator monitors and also 
display the subset of SOLs associated with facilities that are most 
critical to the portions of the Bulk-Power System that are monitored by 
the reliability coordinator.
    15. Under proposed new Reliability Standards, IRO-008-1, IRO-009-1, 
and IRO-010-1a, reliability coordinators must monitor and analyze IROLs 
within their Wide-Area to prevent instability, uncontrolled separation, 
or cascading outages that adversely impact the reliability of the 
interconnection. These Reliability Standards would not require the 
reliability coordinator to monitor and analyze SOLs other than IROLs 
within their reliability coordinator area. Similarly, NERC's proposed 
revisions to Reliability Standards EOP-001-1, IRO-002-2, IRO-004-2, 
IRO-005-3, TOP-003-1, TOP-005-2, and TOP-006-2, inter alia, would 
remove requirements for the reliability coordinator to monitor and 
analyze SOLs other than IROLs.
Discussion
    16. We believe that it is appropriate to develop requirements for 
Reliability Standards that offer a clear division of responsibilities 
among reliability coordinators and transmission operators. We, 
therefore, propose to approve NERC's proposed division of 
responsibility for SOLs and IROLs among reliability coordinators and 
transmission operators. Although we support NERC's proposal and propose 
here to approve it with only a limited directive regarding one proposed 
definition, we are also seeking comments from NERC and industry to 
obtain further information and ensure that there will not be gaps in 
the analysis of SOLs by reliability coordinators going forward, 
particularly those SOLs that could become IROLs. NERC acknowledges in 
its filing that the transmission operator must develop and share its 
SOLs with its reliability coordinator, and the reliability coordinator 
must develop and share any SOLs it develops with its transmission 
operator.\23\ NERC also states that the reliability coordinator 
monitors the status of some, but not all, SOLs.\24\ In addition, the 
Commission is aware that NERC is currently working on a project to 
identify a subset of SOLs, other than IROLs, that a reliability 
coordinator must continuously monitor and analyze.\25\ Taken together, 
NERC's statements and its ongoing project indicate a need for 
reliability coordinators to continue to analyze certain SOLs. We, 
therefore, seek comment on whether there is a need for reliability 
coordinators to continue to analyze, in addition to continuing to 
monitor and coordinate data on,\26\ SOLs other than IROLs.
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    \23\ Id.
    \24\ Id.
    \25\ NERC identifies this as ``Project 2007-03: Real-time 
Operations,'' available at http://www.nerc.com/filez/standards/Real-
time_Operations_Project_2007-03.html.
    \26\ Existing reliability standards that NERC does not propose 
to change here continue to require reliability coordinators to 
monitor SOLs. See Reliability Standard IRO-002-1 Requirement R6.
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    17. Since the ERO has stated that responsibility for the SOLs is 
shared between the reliability coordinator and their transmission 
operators, we also believe it may be beneficial for the reliability 
coordinator to have a documented methodology for identifying the SOL 
information it needs to fulfill its responsibilities for monitoring, 
day ahead and real-time assessments, and operational control within the 
reliability coordinator's area. We seek comment on this matter.
    18. In addition, we request comment from NERC, reliability 
coordinators, and other interested entities on the current practices of 
reliability coordinators and transmission operators with respect to 
coordinating operational responsibilities for monitoring, day ahead and 
real-time assessments; and operating SOLs and IROLs, the practical 
division of responsibilities for preventing and mitigating SOL and IROL 
violations, and the monitoring capabilities of the reliability 
coordinator with respect to IROLs as well as SOLs. The Commission 
further seeks comment as to whether a reliability coordinator can 
provide an accurate assessment of the Bulk-Power System to its 
transmission operators on a Wide-Area basis, without evaluating: (1) 
The operating environment on SOLs that will impact the transmission 
operators within the reliability coordinator's areas; (2) SOLs that 
have the potential to become IROLs; and (3) the existing IROLs within 
the reliability coordinator area. In addition, the Commission seeks 
comments as to whether a transmission operator can provide reliable 
operating assessments or make reliable operating instructions on an SOL 
that is on the border between two different transmission operator's 
areas. The Commission also requests comment on whether the reliability 
coordinator should have responsibility to monitor certain SOLs other 
than IROLs, and whether such a responsibility would place an 
unreasonable burden on reliability coordinators. If a reliability 
coordinator should monitor certain SOLs other than IROLs, comments 
should address in detail how reliability coordinators should determine 
which SOLs to monitor.
    19. The Commission has noted that NERC Standard IRO-006, 
Transmission

[[Page 71617]]

Loading Relief (TLR), requires the reliability coordinators in the 
Eastern Interconnection to relieve overloads on the facilities modeled 
in the Interchange Distribution Calculator (IDC). IRO-006 requires the 
reliability coordinator to model the SOLs and IROLs in the IDC to 
perform the TLR procedures. The Commission seeks comments on how the 
reliability coordinators in the Eastern Interconnections selects the 
SOLs for evaluation by the IDC and the extent of any burden this has 
caused the reliability coordinator.
    20. The NERC Functional Model is a reference document developed by 
NERC that outlines functions for each responsible entity in the NERC 
Reliability Standards.\27\ NERC explains in its filing that the NERC 
Functional Model was developed by first identifying all of the 
operating tasks necessary for reliability, and then assigning each of 
these operating tasks to a single functional entity.\28\ NERC states 
that this approach results in a clear identification of a single 
functional entity with responsibility for each reliability task. 
However, NERC also states that in later versions of the Functional 
Model, there are circumstances where the Functional Model assigns some 
activities to more than one planning entity.\29\ NERC explains that, 
under the Functional Model, the reliability coordinator is responsible 
for identifying the subset of SOLs known as IROLs and that the 
transmission operator is responsible for other SOLs. But the Functional 
Model assigns a much broader role to the reliability coordinator to 
maintain the real-time operating reliability of the bulk electric 
system within its area. The Commission seeks comments from NERC and the 
public as to how the current Functional Model represents the 
delineation of assessment and operating responsibilities between the 
reliability coordinator and transmission operator with respect to SOLs 
and IROLs.
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    \27\ NERC, Reliability Functional Model, version 5 at 30 (Nov. 
2009), available at http://www.nerc.com/files/Functional_Model_
V5_Final_2009Dec1.pdf. NERC developed the current version of the 
Functional Model after it developed the proposed Reliability 
Standards.
    \28\ NERC Petition at 7.
    \29\ Id. at 7 n.9.
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    21. Based on the foregoing, the Commission proposes to approve the 
proposed new and revised Reliability Standards without modification 
(with the exception of the limited directive proposed below), as they 
appear to be an improvement over the existing Reliability Standards 
with respect to the division of responsibilities between reliability 
coordinators and transmission operators. Our intent in seeking comments 
from NERC and industry in this NOPR is to better understand the 
proposed division of responsibilities, as well as the future 
modifications to those responsibilities that NERC intends to pursue.

B. Proposed New Reliability Standards

1. IRO-008-1
    22. Proposed Reliability Standard IRO-008-1 has the stated purpose 
of preventing instability, uncontrolled separation, or cascading 
outages that adversely impact the reliability of the interconnection by 
ensuring that the Bulk Electric System is assessed during the 
operations horizon. The proposed Reliability Standard applies to 
reliability coordinators. IRO-008-1 requires the reliability 
coordinator to use analyses and assessments as methods of achieving the 
stated goal. The Reliability Standard requires analysis of the 
reliability coordinator's Wide-Area \30\ ahead of time and during real-
time. It also requires communication with the entities that need to 
take specific operational actions based on the analyses and 
assessments.
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    \30\ The term ``Wide-Area'' is defined in the NERC Glossary, 
approved by the Commission. As defined, Wide-Area includes not only 
the reliability coordinator's Area, but also critical flow and 
status information from adjacent reliability Coordinator areas as 
determined by detailed system studies to allow the calculation of 
IROLs. See NERC Glossary available at http://www.nerc.com/docs/
standards/rs/Glossary_of_Terms_2010April20.pdf.
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    23. Reliability Standard IRO-008-1 contains three requirements. 
Requirement R1 requires each reliability coordinator to perform an 
Operational Planning Analysis to assess whether the planned operations 
for the next day within its Wide Area, will exceed any of its IROLs 
during anticipated normal and contingency event conditions. Requirement 
R2 requires the reliability coordinator to perform a Real-Time 
Assessment at least once every 30 minutes to determine if its Wide Area 
is exceeding any IROLs or is expected to exceed any IROLs. Requirement 
R3 requires a reliability coordinator to share the results of an 
Operational Planning Analysis or Real-Time Assessment that indicates 
the need for specific operational actions to prevent or mitigate an 
instance of exceeding an IROL with those entities that are expected to 
take those actions.
    24. NERC explains that IRO-008-1, Requirement R1 does not specify 
any single application program that all reliability coordinators must 
use because the Requirement assumes that the reliability coordinator 
has a suite of applications that it can use to conduct its assessment, 
verified as part of the certification process. NERC notes that having 
the ability to conduct a day-ahead contingency analysis is a 
requirement for reliability coordinator certification.
    25. NERC also requests approval of two new terms that appear in 
IRO-008-1: ``Operational Planning Analysis'' and ``Real-time 
Assessment.'' Operational Planning Analysis is defined as:

    An analysis of the expected system conditions for the next day's 
operation. (That analysis may be performed either a day ahead or as 
much as 12 months ahead.) Expected system conditions include things 
such as load forecast(s), generation output levels, and known system 
constraints (transmission facility outages, generator outages, 
equipment limitations, etc.).

NERC states that the definition was designed to provide greater 
specificity regarding the day-ahead study. NERC explains that the term 
``unique'' used in the currently-effective IRO-004-1 causes confusion. 
NERC states that in the event there are no changes to the expected 
conditions from one day to the next, the reliability coordinator would 
not be forced to conduct a new analysis of the expected system 
conditions solely to have documentation for compliance.
    26. The proposed term ``Real-time Assessment'' is defined as ``[a]n 
examination of existing and expected system conditions, conducted by 
collecting and reviewing immediately available data.'' The purpose of 
the new term is to assure that the reliability coordinator is required 
to conduct a real-time assessment, including situations when the 
reliability coordinator is operating without its primary control 
facilities, by collecting and reviewing available data. NERC explains 
that the definition of Real-Time Assessment is purposefully ambiguous 
to allow the assessment to be conducted either through the energy 
management system or manually.
NOPR Proposal
    27. We agree with NERC that the proposed Reliability Standard IRO-
008-1 would prevent instability, uncontrolled separation, or cascading 
outages that adversely impact the reliability of the interconnection by 
ensuring that the bulk electric system is assessed during the 
operations horizon. In addition, the Commission recognizes NERC's 
effort to create a body of IRO Reliability Standards that clearly 
define which functional entity has the ultimate responsibility for SOLs 
and IROLs. Accordingly, pursuant to section 215(d)(2) of the FPA, the 
Commission proposes to approve Reliability

[[Page 71618]]

Standards IRO-008-1, as just, reasonable, not unduly discriminatory or 
preferential, and in the public interest. To ensure that the proposed 
changes are supported by the Functional Model, the Commission requests 
comment whether the proposed Reliability Standards, such as IRO-008-1, 
appropriately resolve the division of responsibilities for SOLs and 
IROLs or whether some level of sharing of responsibility needs to 
exist.
    28. The Commission also proposes to approve the addition of two new 
definitions to the NERC Glossary: ``Operational Planning Analysis'' and 
``Real-time Assessment'' with limited modification, as discussed below. 
Although the proposed definition of Operational Planning Analysis would 
permit entities to use an analysis of the expected system conditions 
for the next day's operation that was performed up to twelve months 
earlier, the discretion to use an existing analysis is limited to 
circumstances where the expected system conditions, such as load 
forecasts, generation output levels, and known system constraints are 
the same for both days. Nevertheless, the Commission requests comments 
from NERC and the public on the prudence of using an Operational 
Planning Analysis up to twelve months old. We request comment on 
whether this timeframe is reasonable or whether the timeframe should be 
shorter to ensure that the analysis is not outdated. In addition, the 
Commission also seeks comments from NERC and the public on whether the 
definition should include measurable criteria needed to determine 
whether it is appropriate to use an existing analysis.
    29. In addition, the Commission seeks comment on the meaning of 
``immediately available data'' within the proposed definition of Real-
Time Assessment. Requirement R6 of proposed Reliability Standard IRO-
002-2 would require reliability coordinators to have adequate analysis 
capabilities such as state estimation, pre- and post-contingency 
analysis capabilities (thermal, stability, and voltage), and wide-area 
overview displays.\31\ Thus, it appears that any immediately available 
data used by the reliability coordinator in the development of a Real-
time Assessment should be data obtained from one of these analysis 
capabilities. We believe this could be clearer. Accordingly, under 
section 215(d)(5) of the FPA, the Commission proposes to direct NERC to 
modify the definition of ``Real-time Assessment'' to specify that the 
type of data to be relied upon by a reliability coordinator in 
conducting a Real-time Assessment must be based on adequate analysis 
capabilities such as those referenced in Requirement R6 of IRO-002-2 
when the tools are available.
---------------------------------------------------------------------------

    \31\ As discussed below, NERC proposes to revise IRO-002-1 by 
removing one provision, Requirement R2. Thus, Requirement R6 of 
proposed IRO-002-2 is the same as Requirement R7 of the existing 
version 1 Reliability Standard.
---------------------------------------------------------------------------

2. IRO-009-1
    30. As proposed, Reliability Standard IRO-009-1 is designed to 
prevent instability, uncontrolled separation, or cascading outages that 
adversely impact the reliability of the interconnection by ``ensuring 
prompt action to prevent or mitigate instances of exceeding [IROLs].'' 
Proposed Reliability Standard IRO-009-1 applies only to reliability 
coordinators.
    31. For each IROL that the reliability coordinator identifies one 
or more days in advance, the reliability coordinator must, under 
Requirements R1 and R2, have one or more operating processes, 
procedures, or plans that identify actions it shall take that can be 
implemented in time to prevent exceeding those IROLs and to mitigate 
the magnitude and duration of exceeding that IROL such that the IROL is 
alleviated within the maximum time duration allowed for a violation of 
an IROL. Reliability Standard IRO-009-1 refers to the maximum response 
period for alleviating an IROL as its ``IROL Tv.'' \32\ Under 
Requirements R3 and R4, the reliability coordinator must use those 
operating processes, procedures, or plans to prevent and mitigate 
IROLs. If reliability coordinators cannot agree on the value for an 
IROL or its IROL Tv, Requirement R5 would require each reliability 
coordinator that monitors that facility to use the most conservative 
value.
---------------------------------------------------------------------------

    \32\ The NERC Glossary of Terms defines ``IROL Tv'' as:
    The maximum time that an Interconnection Reliability Operating 
Limit can be violated before the risk to the interconnection or 
other Reliability Coordinator Areas becomes greater than acceptable. 
Each Interconnection Reliability Operating Limit's Tv shall be less 
than or equal to 30 minutes.
---------------------------------------------------------------------------

NOPR Proposal
    32. The Commission agrees that having action plans developed and 
implemented with respect to IROLs to prevent instability, uncontrolled 
separation, or cascading outages that adversely impact the reliability 
of the interconnection increases the likelihood that reliability 
coordinators will take appropriate action. Accordingly, under section 
215(d)(2) of the FPA, the Commission proposes to approve Reliability 
Standard IRO-009-1, as just, reasonable, not unduly discriminatory or 
preferential, and in the public interest. However, as discussed above, 
the Commission requests comment on the extent that reliability 
coordinators should have action plans developed and implemented with 
respect to other SOLs apart from IROLs and if so, which SOLs.
3. IRO-010-1a
    33. NERC proposes the addition of a new Reliability Standard, IRO-
010-1a to the current suite of IRO Reliability Standards. IRO-010-1a is 
designed to prevent instability, uncontrolled separation, or cascading 
outages that adversely impact the reliability of the interconnection by 
mandating that the reliability coordinator have the data it needs to 
monitor and assess the operation of its reliability coordinator Area.
    34. The requirements in the Reliability Standard specify a formal 
request process for the reliability coordinator to explicitly identify 
the data and information it needs for reliability; and require the 
entities with the data to provide it as requested. The Reliability 
Standard applies to the reliability coordinator and to the other 
functional entities that must supply data to the reliability 
coordinator.\33\ This includes entities that have been identified as 
owners, users, or operators of the bulk-power system.
---------------------------------------------------------------------------

    \33\ The requirements in the standard are specifically 
applicable to the following functional entities: (1) Reliability 
coordinator; (2) balancing authority; (3) generator owner; (4) 
generator operator; (5) interchange authority; (6) load-serving 
entity; (7) transmission operator; and (8) transmission owner.
---------------------------------------------------------------------------

    35. Because the interpretation for IRO-010-1 was completed before 
the filing of IRO-010-1, NERC requests Commission approval of IRO-010-
1a, which includes the standard as interpreted. The WECC Reliability 
Coordination Subcommittee requested clarification on: (1) The type of 
data to be supplied to the reliability coordinator; (2) which entities 
are ultimately responsible for ensuring data are provided; and (3) what 
actions are expected of the reliability coordinator regarding a 
``mutually acceptable format.''
    36. In response to the questions posed by the WECC Reliability 
Coordination Subcommittee, NERC's interpretation team clarified that 
the data to be supplied in Requirement R3 applies to the documented 
specification for data and information referenced in Requirement R1. 
They also explained that the intent of Requirement R3 is for each 
responsible entity to ensure that its data and information (as stated 
in the documented specification in

[[Page 71619]]

Requirement R1) are provided to the reliability coordinator. NERC's 
interpretation team stated that another entity may provide that data or 
information to the reliability coordinator on behalf of the responsible 
entity, but the responsibility remains with the responsible entity. 
Finally, they explained that Requirement R1.2 mandates that the parties 
will reach a mutual agreement with respect to the format of the data 
and information. If the parties can not mutually agree on the format, 
it is expected that they will negotiate to reach agreement or enter 
into dispute resolution to resolve the disagreement.\34\
---------------------------------------------------------------------------

    \34\ NERC Petition at 108.
---------------------------------------------------------------------------

NOPR Proposal
    37. Under section 215(d)(2) of the FPA, the Commission proposes to 
approve Reliability Standard IRO-010-1a, including the proposed 
interpretation, as just, reasonable, not unduly discriminatory or 
preferential, and in the public interest. However, the Commission notes 
that the requirements of Reliability Standard IRO-010-1a do not require 
reliability coordinators to specify a list of minimum data needed for 
reliable operation of the Bulk-Power System. The Commission is 
concerned that, without such a minimum list, neighboring reliability 
coordinators could experience problems regarding compatibility and, 
therefore, common understanding of data. For example, if differing data 
requirements were specified by adjacent reliability coordinators, the 
analysis performed by one could indicate a more severe result from a 
possible contingency and result in conflicting operating procedures for 
mitigation of risk to the Bulk-Power System. Therefore, the Commission 
requests comments from the ERO and industry on whether a minimum list 
of data is necessary for the effective sharing of data between 
neighboring reliability coordinators and, if so, what data should be 
included. The Commission also requests comments from NERC and the 
industry on how compatibility of data between neighboring reliability 
coordinators can be assured absent a list of minimum data as part of 
this proposed Reliability Standard.

C. Proposed Revised Reliability Standards

1. EOP-001-1
    38. NERC proposes to retire Requirement R2 of Reliability Standard 
EOP-001-0. To implement this revision, NERC proposes a revised 
Reliability Standard EOP-001-1. The purpose of EOP-001-1 is to require 
each transmission operator and balancing authority to develop, 
maintain, and implement a set of plans to mitigate operating 
emergencies. These plans need to be coordinated with other transmission 
operators and balancing authorities, and the reliability coordinator. 
Revised Reliability Standard EOP-001-1 would apply only to balancing 
authorities and transmission operators.
    39. NERC contends that, upon IRO-009-1 becoming effective, 
Requirement R2 of EOP-001-0 should be retired. Under Requirement R2 
transmission operators must have an emergency load reduction plan for 
all identified IROLs. NERC contends that this requirement would no 
longer be appropriate upon IRO-009-1 becoming effective because the 
reliability coordinator, not the transmission operator, is responsible 
for developing plans for mitigating IROLs. Accordingly, NERC requests 
approval of EOP-001-1, which is identical to existing Reliability 
Standard EOP-001-0 except for the retirement of Requirement R2.
    40. NERC contends that the proposed new Requirements R1 and R2 of 
IRO-009-1 combined with the revisions in proposed Reliability Standard 
EOP-001-1 address the Commission's directives in Order No. 693 to 
modify EOP-001-0 to include the reliability coordinator as an 
applicable entity and to require the reliability coordinator to act to 
mitigate IROL violations within 30 minutes.\35\ In developing IRO-009-
1, NERC states that the drafting team determined that there are some 
IROLs that must be resolved in a time frame that is shorter than 30 
minutes. Accordingly, Requirement R2 of IRO-009-1 requires that each 
action plan developed to resolve an IROL must be capable of being 
executed such that the IROL is relieved within its IROL Tv. In 
addition, Requirement R4 of IRO-009-1 requires the reliability 
coordinator to act, without delay, when actual system conditions show 
that there is an instance of exceeding an IROL.
---------------------------------------------------------------------------

    \35\ Order No. 693, FERC Stats. & Regs. ] 31,242 at P 548, 556, 
566.
---------------------------------------------------------------------------

NOPR Proposal
    41. Under section 215(d)(2) of the FPA, the Commission proposes to 
approve Reliability Standard EOP-001-1 as just, reasonable, not unduly 
discriminatory or preferential, and in the public interest. The 
Commission also proposes to find that the ERO has satisfied the first 
and second directives from P 566 of Order No. 693.\36\
---------------------------------------------------------------------------

    \36\ The Commission notes that the third and fourth directives 
listed in P 566 of Order No. 693 remain outstanding. Further, the 
Commission directed the ERO to consider a pilot program for 
implementing system states. Order No. 693, FERC Stats. & Regs. ] 
31,242 at P 566.
---------------------------------------------------------------------------

2. IRO-002-2
    42. NERC proposes to retire Requirement R2 of Reliability Standard 
IRO-002-1. To implement this revision, NERC requests Commission 
approval of revised Reliability standard IRO-002-2. The purpose of IRO-
002-2 is to provide reliability coordinators with the information, 
tools and other capabilities that they need to perform their 
responsibilities. IRO-002-2 would apply only to reliability 
coordinators.
    43. Requirement R2 of IRO-002-1 requires each reliability 
coordinator to determine the data requirements to support its 
reliability coordinator tasks and to request such data from its 
transmission operators, balancing authorities, transmission owners, 
generation owners, generation operators, and load-serving entities, or 
adjacent reliability coordinators. NERC explains that proposed 
Reliability Standard IRO-010-1a (discussed above) requires the 
reliability coordinator to develop and distribute a data specification 
to ensure that entities provide data as needed to support monitoring, 
analyses, and assessments. NERC contends that the proposed requirements 
are more explicit than the associated requirement in Reliability 
Standard IRO-002-1.
    44. Reliability Standard IRO-002-2 continues to require each 
reliability coordinator to monitor SOLs other than IROLs both within 
its reliability coordinator area and in surrounding reliability 
coordinator areas. Under Requirement R4 of IRO-002-2, each reliability 
coordinator must have detailed real-time monitoring capability of its 
reliability coordinator area and sufficient monitoring capability of 
its surrounding reliability coordinator areas to ensure that potential 
or actual SOLs or IROL violations are identified. In addition, under 
Requirement R5, each reliability coordinator must monitor bulk electric 
system elements such as generators, transmission lines, buses, 
transformers and breakers that could result in SOL or IROL violations 
within its reliability coordinator area.
    45. In Order No. 693, the Commission directed the ERO to develop a 
modification to IRO-002-1 that requires a minimum set of capabilities 
that should be made available to reliability coordinators. NERC 
acknowledges that the proposed modification does not

[[Page 71620]]

address this directive. NERC states that this directive is being 
considered in Project 2009-02--Real-time Tools and Analysis 
Capabilities.
NOPR Proposal
    46. Under section 215(d)(2) of the FPA, the Commission proposes to 
approve Reliability Standard IRO-002-2. The Commission proposes to find 
that the data specification requirements of proposed Reliability 
Standard IRO-001-1a are more explicit than the direction provided in 
Requirement R2 of IRO-002-1. In addition, the Commission accepts NERC's 
commitment to develop a minimum set of capabilities that should be made 
available to reliability coordinators.
3. IRO-004-2
    47. NERC proposes to revise IRO-004-1 by retiring Requirements R1 
through R6. To implement these revisions, NERC requests Commission 
approval of Reliability Standard IRO-004-2. The purpose of IRO-004-2 is 
to require each reliability coordinator to conduct next-day reliability 
analyses for its reliability coordinator area to ensure the bulk 
electric system can be operated reliably in anticipated normal and 
contingency conditions. IRO-004-2 would apply to balancing authorities, 
transmission operators, and transmission service providers.
    48. NERC states that, upon approval of proposed IRO-008-1, 
Requirement R1 of the currently-effective IRO-004-1 should be retired 
because the requirement only requires a next-day reliability analysis 
of its own reliability coordinator area as opposed to its Wide-Area, 
which also would include critical flow and status information from 
adjacent reliability coordinator areas to allow the calculation of 
IROLs. NERC explains that because proposed IRO-008-1 requires the 
reliability coordinator to assess a wider area than is currently 
required by IRO-004-1, the reliability coordinator is required to 
continuously look beyond its own area boundaries and assess a broader 
portion of the interconnected Bulk-Power System. NERC further states 
that the purpose of conducting a day-ahead analysis is not to 
``ensure'' but to ``assess'' the system and, thus, Requirement R1 of 
currently-effective IRO-004-1 is inaccurate.
    49. NERC also seeks to retire Requirement R2 of IRO-004-1, which 
requires each reliability coordinator to ``pay particular attention to 
parallel flows to ensure one reliability coordinator area does not 
place an unacceptable or undue burden on an adjacent reliability 
coordinator area.'' \37\ NERC states that the phrase ``to pay 
particular attention to'' is neither clear nor measurable. NERC asserts 
that the requirements in currently-effective IRO-014, IRO-015, and IRO-
016 are aimed at ensuring that reliability coordinators coordinate 
their actions with one another and act in the best interest of the 
interconnection as a whole. In addition, NERC explains that, under the 
Functional Model, the transmission operator is responsible for the 
real-time operation of the transmission system with the reliability 
coordinator providing oversight of the transmission operator's actions, 
directing additional or alternate actions when needed. NERC states that 
the requirements proposed in the new IRO Reliability Standards focus 
specifically on IROLs and are inclusive of any reliability implications 
due to parallel flows.
---------------------------------------------------------------------------

    \37\ Reliability Standard IRO-004-1, Requirement R2.
---------------------------------------------------------------------------

    50. In support of retiring Requirements R1 and R2 of IRO-004-1, 
NERC posits that under the Functional Model, the reliability 
coordinator is the functional entity with primary responsibility for 
IROLs and the transmission operator is the functional entity with 
primary responsibility for SOLs. NERC states that, under certain 
circumstances, the transmission operator may request the assistance of 
its reliability coordinator in developing an SOL but the responsibility 
for addressing the SOL remains with the transmission operator.\38\ NERC 
explains that, under the Functional Model and Requirement R11 of 
Reliability Standard TOP-002-2, the transmission operator is 
responsible for conducting analyses to identify where there may be 
instances of exceeding SOLs. NERC also states that, under TOP-008-1, 
the transmission operator is responsible for taking actions to either 
prevent or mitigate instances of exceeding SOLs. NERC states that, by 
contrast, it is the reliability coordinator that is responsible for 
ensuring that IROLs are developed for its reliability coordinator area 
in accordance with a methodology developed by the reliability 
coordinator. Further, NERC states that the transmission operator must 
share its SOLs with its reliability coordinator, and the reliability 
coordinator must share any SOLs it develops with its transmission 
operator. NERC states that the reliability coordinator monitors the 
status of some, but not all, SOLs.
---------------------------------------------------------------------------

    \38\ See Reliability Standard TOP-008-1, requiring transmission 
operators to take action to prevent or mitigate violations of SOLs.
---------------------------------------------------------------------------

    51. NERC also contends that, upon proposed Reliability Standard 
IRO-009-1 becoming effective, Requirements R3 and R6 of currently-
effective IRO-004-0 should be retired. Under Requirement R3 of IRO-004-
0, reliability coordinators must, in conjunction with its transmission 
operators and balancing authorities, develop action plans, including 
for reducing load to return transmission loading to within acceptable 
SOLs or IROLs. NERC states that the use of the phrase, ``in conjunction 
with'' is not supported by the responsibilities of the reliability 
coordinator in the Functional Model and would be inconsistent with the 
requirements of proposed Reliability Standard IRO-009-1. NERC also 
states that proposed Requirement R3 of IRO-009-1 includes language that 
is more explicit than the language in Requirement R6 of existing 
Reliability Standard IRO-004-1.
    52. Finally, NERC proposes to retire Requirements R4 and R5 from 
IRO-004-1. Requirement R4 requires each transmission operator, 
balancing authority, transmission owner, generator owner, generator 
operator, and load-serving entity in the reliability coordinator area 
to provide information required for system studies. NERC proposes to 
retire Requirement R4 because it identifies only a fraction of the 
reliability-related data needed by the reliability coordinator. 
Requirement R5 requires each reliability coordinator to share the 
results of its system studies with other reliability coordinators and 
transmission operators, balancing authorities, and transmission service 
providers within its reliability coordinator area. NERC states that 
proposed Reliability IRO-010-1a offers a suitable replacement for 
currently-effective Requirements R4 and R5 because IRO-010-1a requires 
reliability coordinators to know, in advance, what data and information 
it needs and what data and information it needs to share with other 
reliability entities. In addition, requirement R3 of proposed 
Reliability Standard IRO-008-1 would require the reliability 
coordinator to share the results of its analyses with entities within 
its reliability coordinator area.
NOPR Proposal
    53. Under section 215(d)(2) of the FPA, the Commission proposes to 
approve Reliability Standard IRO-004-2, as just, reasonable, not unduly 
discriminatory or preferential, and in the public interest. The 
Commission recognizes NERC's efforts to more clearly define which 
functional entity has the ultimate responsibility for SOLs

[[Page 71621]]

and IROLs, and to synchronize existing standards with the proposed new 
IRO Reliability Standards. We propose to find that the requirements 
proposed for retirement from IRO-004-1 are appropriately addressed in 
new Reliability Standards IRO-008-1, IRO-009-1, and IRO-010-1a.
4. IRO-005-3
    54. NERC proposes to retire Requirement R2, R3, R5, R16, and R17 of 
currently-effective Reliability Standard IRO-005-2, and to modify 
Requirements R9, R13, and R14. To implement these revisions, NERC 
requests Commission approval of proposed Reliability Standard IRO-005-
3. The purpose of proposed Reliability Standard IRO-005-3 is to require 
the reliability coordinator to be continuously aware of conditions 
within its reliability coordinator area and include this information in 
its reliability assessments. In addition, the reliability coordinator 
must monitor the bulk electric system parameters that may have 
significant impacts upon the reliability coordinator area and 
neighboring reliability coordinator areas. IRO-005-3 would apply to 
reliability coordinators, balancing authorities, transmission 
operators, transmission service providers, generator operators, load-
serving entities, and purchasing-selling entities.
    55. NERC contends that, upon the new IRO Reliability Standards 
becoming effective, Requirements R2, R3, R5, R16, and R17 of IRO-005-2 
should be retired and Requirements R9, R13, and R14 should be modified. 
Except for Requirement R2, all of the requirements proposed for 
retirement set responsibilities for the reliability coordinator to be 
continuously aware of SOLs and IROLs within its reliability coordinator 
area and to identify the cause for each SOL and IROL. Similarly, all of 
the requirements proposed for modification include requirements for the 
reliability coordinator to address SOLs and for the transmission 
operator to address IROLs. NERC contends that these existing 
requirements should be retired or modified in light of the division of 
responsibilities between reliability coordinators and transmission 
operators expressed in new Reliability Standard IRO-009-1.
    56. Requirement R2 requires the reliability coordinator ``to be 
aware of'' all interchange transactions that wheel through its 
reliability coordinator area. NERC contends that it is not possible to 
measure how an entity is ``aware of'' specific information. In 
addition, NERC states that the e-tag system that has been implemented 
no longer requires the reliability coordinator to collect and relay 
interchange information to other entities. If a reliability coordinator 
needs this information, NERC states that the reliability coordinator 
can add this item to the list of data and information on its data 
specification under proposed Requirement R1 of IRO-010-1a.
NOPR Proposal
    57. Under section 215(d)(2) of the FPA, the Commission proposes to 
approve Reliability Standard IRO-005-3, as just, reasonable, not unduly 
discriminatory or preferential, and in the public interest. The 
Commission recognizes NERC's efforts to more clearly define which 
functional entity has the ultimate responsibility for SOLs and IROLs, 
and to synchronize existing standards with the proposed new IRO 
Reliability Standards. We propose to find that the requirements of IRO-
005-2 proposed for retirement and modification are appropriately 
addressed in new Reliability Standards IRO-008-1, IRO-009-1, and IRO-
010-1a.
5. TOP-003-1
    58. NERC proposes to modify Requirement R1.2 of currently-effective 
Reliability Standard TOP-003-0. To implement this revision, NERC 
requests approval of proposed Reliability Standard TOP-003-1. The 
purpose of TOP-003-1 is to require balancing authorities, transmission 
operators, and reliability coordinators to plan and coordinate 
scheduled generator and transmission outages that may affect the 
reliability of interconnected operations. TOP-003-1 would apply to 
generator operators, transmission operators, balancing authorities, and 
reliability coordinators.
    59. NERC explains that Requirement R1.2 of TOP-003-0 includes two 
distinct activities--a requirement for the transmission operator to 
provide the reliability coordinator and other entities with daily 
outage information and a requirement for the reliability coordinator to 
establish outage reporting requirements. NERC contends that both 
elements of Requirement R1.2 are captured in proposed Reliability 
Standard IRO-010-1a. NERC proposes to remove the transmission 
operator's obligation to provide daily outage information to 
reliability coordinators and strike the requirement for the reliability 
coordinator to establish outage reporting requirements.
    According to NERC, Requirement R1 of proposed IRO-010-1a requires 
the reliability coordinator to specify what data and information it 
needs, as well as the frequency and format for providing that data and 
information. NERC states that, because the reliability coordinator 
needs outage data for modeling and analysis, the specification will 
include outage data. Requirement R3 of IRO-010-1a requires entities to 
provide data and information to the reliability coordinator in 
accordance with the reliability coordinator's specifications. NERC 
states that if TOP-003-0 Requirement R1.2 is not modified, it will be 
redundant with IRO-010-1a, Requirement R3.
NOPR Proposal
    60. Under section 215(d)(2) of the FPA, we propose to approve 
Reliability Standard TOP-003-1, as just, reasonable, not unduly 
discriminatory or preferential, and in the public interest. We propose 
to find that the requirements of currently-effective Reliability 
Standard TOP-003-0 that NERC proposed for modification are 
appropriately addressed in new Reliability Standard IRO-010-1a. 
However, under Requirement R3, it is incumbent on the reliability 
coordinator to request sufficient scheduled outage data. The Commission 
is concerned that IRO-010-1a does not specify outage coordination data 
and the reliability coordinator may not receive adequate outage 
coordination data to support the Operational Planning Analysis. 
Therefore, the Commission seeks comments from NERC and the public on 
whether IRO-010-1a should specify the necessary outage coordination 
data.
6. TOP-005-2
    61. NERC proposes to retire Requirements R1 and R1.1 of currently-
effective Reliability Standard TOP-005-1 and modify Attachment 1 of the 
Reliability Standard. To implement these revisions, NERC requests 
approval of proposed Reliability Standard TOP-005-2. The purpose of 
TOP-005-2 is to ensure reliability entities have the operating data 
needed to monitor system conditions within their areas. TOP-005-2 would 
apply to transmission operators, balancing authorities, and purchasing 
selling entities.
    62. Requirement R1 of TOP-005-1 requires transmission operators to 
provide the reliability coordinator with the data and information that 
the reliability coordinator needs to perform its reliability-related 
tasks. Requirement R1.1 of TOP-005-1 requires reliability coordinators 
to identify the data requirements, listed in Attachment 1 of TOP-005-1, 
and any additional operating information requirements relating to the 
operation of the Bulk-Power System with its reliability

[[Page 71622]]

coordinator area. NERC states that Requirement R1 implies that the 
reliability coordinator will limit its use of the data and information 
it collects to operations within its reliability coordinator area. 
According to NERC, this does not support the Functional Model, which 
requires the reliability coordinator to monitor the Wide-Area. NERC 
states that, under other Reliability Standards such as IRO-014-1 and 
IRO-015-1, each reliability coordinator is expected to coordinate the 
activities within its reliability coordinator area with other 
reliability coordinators.
    63. NERC states that, under proposed Reliability Standard IRO-010-
1a, each reliability coordinator must document what data and 
information it needs and which entities must provide that data. NERC 
explains that the reliability coordinator needs this data to perform 
reliability assessments and for real-time monitoring. Under the 
Functional Model, the reliability coordinator collects data and 
information not just from transmission operators and balancing 
authorities, but also from generator operators, load-serving entities, 
transmission owners, and generator owners.
    64. NERC also proposes conforming revisions to Attachment 1 to TOP-
005-2. As currently written, Attachment 1 of TOP-005-1 lists the types 
of data that reliability coordinators, balancing authorities, and 
transmission operators are expected to provide, and are expected to 
share with each other. Consistent with the proposed revisions in 
Reliability Standard TOP-005-2, NERC proposes to remove references to 
the reliability coordinator from Attachment 1.
NOPR Proposal
    65. Under section 215(d)(2) of the FPA, the Commission proposes to 
approve Reliability Standard TOP-005-2, as just, reasonable, not unduly 
discriminatory or preferential, and in the public interest. The 
Commission recognizes NERC's efforts to more clearly define the 
reliability coordinator's need to know, in advance, what data is 
needed, insure the timely availability of the data; and how that data 
will be communicated to other functional entities. We propose to find 
that the requirements of TOP-005-1 that are proposed for retirement are 
appropriately addressed in new Reliability Standard IRO-010-1a. We are 
concerned, however, about whether the proposal adequately ensures the 
compatibility of data between neighboring reliability coordinators. 
Having compatible data allows for an essential level of 
interoperability. The Commission requests comment from the reliability 
coordinators and the industry on whether a list of minimum ``Electric 
System Reliability Data,'' such as shown in Attachment 1 of currently-
effective Reliability Standard TOP-005-1, is beneficial for reliability 
coordinators to meet the requirements of IRO-008-1 and IRO-009-1.
7. TOP-006-2
    66. NERC proposes to modify Requirement R4 of currently-effective 
Reliability Standard TOP-006-1. To implement this revision, NERC 
requests approval of proposed Reliability Standard TOP-006-2. The 
purpose of TOP-006-2 is to ensure critical reliability parameters are 
monitored in real-time. Its requirements would be applicable to 
transmission operators, balancing authorities, generator operators, and 
reliability coordinators.
    67. Requirement R4 of TOP-006-1 requires each reliability 
coordinator, transmission operator, and balancing authority to have 
information, including weather forecasts and past load patterns, 
available to predict the system's near-term load pattern. NERC proposes 
to modify Requirement R4 by removing the reference to reliability 
coordinators. NERC states that the information identified in existing 
Requirement R4 of TOP-006-1 is not inclusive, and is addressed more 
globally for the reliability coordinator in Requirements R1 and R3 of 
the proposed new Reliability Standard IRO-010-1a. Proposed Requirement 
R1 of IRO-010-1a requires each reliability coordinator to have a 
documented specification for data and information to build and maintain 
models to support real-time monitoring, operational planning analyses, 
and real-time assessments of its reliability coordinator area to 
prevent instability, uncontrolled separation, and cascading outages. 
Requirement R3 of IRO-010-1a requires each balancing authority, 
generator owner, generator operator, interchange authority, load-
serving entity, reliability coordinator, transmission operator, and 
transmission owner to provide data and information, as specified, to 
their reliability coordinator.
NOPR Proposal
    68. Under section 215(d)(2) of the FPA, the Commission proposes to 
approve Reliability Standard TOP-006-2, as just, reasonable, not unduly 
discriminatory or preferential, and in the public interest. The 
Commission recognizes NERC's efforts to more clearly define the 
reliability coordinator's need to know, in advance, what load forecast 
data is needed, the supporting data for the load forecast; and how that 
data will communicated to other functional entities. We propose to find 
that the reliability coordinator functions that are removed from 
Requirement R4 of TOP-006-2 are appropriately addressed in Requirements 
R1 and R3 of new Reliability Standard IRO-010-1a.

D. Violation Severity Levels and Violation Risk Factors

    69. In the event of a violation of a Reliability Standard, NERC 
will establish the initial value range for the corresponding base 
penalty amount. To do so, NERC will assign a violation risk factor for 
each requirement of a Reliability Standard that relates to the expected 
or potential impact of a violation of the requirement on the 
reliability of the Bulk-Power System. In addition, NERC will define up 
to four violation severity levels--Lower, Moderate, High, and Severe--
as measurements for the degree to which the requirement was violated in 
a specific circumstance.
    70. In Order No. 705, the Commission approved 63 of NERC's 72 
proposed violation risk factors for the version one FAC Reliability 
Standards and directed NERC to file violation severity level 
assignments before the version one FAC Reliability Standards become 
effective.\39\ Subsequently, NERC developed violation severity levels 
for each requirement of the Commission-approved FAC Reliability 
Standards, as measurements for the degree to which the requirement was 
violated in a specific circumstance.
---------------------------------------------------------------------------

    \39\ Facilities Design, Connections and Maintenance Reliability 
Standards, Order No. 705, 121 FERC ] 61,296, at P 137 (2007).
---------------------------------------------------------------------------

    71. On June 19, 2008, the Commission issued its Violation Severity 
Level Order approving the violation severity level assignments filed by 
NERC for the 83 Reliability Standards approved in Order No. 693.\40\ In 
that order, the Commission offered four guidelines for evaluating the 
validity of violation severity levels, and ordered a number of reports 
and further compliance filing to bring the remainder of NERC's 
violation severity levels into conformance with the Commission's 
guidelines. The four guidelines are: (1) Violation severity level 
assignments should not have the unintended consequence of lowering the 
current level of compliance; (2) violation severity level assignments 
should ensure uniformity and consistency among all approved Reliability 
Standards in the

[[Page 71623]]

determination of penalties; \41\ (3) violation severity level 
assignments should be consistent with the corresponding requirement; 
and (4) violation severity level assignments should be based on a 
single violation, not a cumulative number of violations.\42\ The 
Commission found that these guidelines will provide a consistent and 
objective means for assessing, inter alia, the consistency, fairness 
and potential consequences of violation severity level assignments. The 
Commission noted that these guidelines were not intended to replace 
NERC's own guidance classifications, but rather, to provide an 
additional level of analysis to determine the validity of violation 
severity level assignments.
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    \40\ Violation Severity Level Order, 123 FERC ] 61,284.
    \41\ Guideline 2 contains two sub-parts: (a) The single 
violation severity level assignment category for binary requirements 
should be consistent and (b) violation severity levels assignments 
should not contain ambiguous language.
    \42\ Violation Severity Level Order, 123 FERC ] 61,284 at P 17.
---------------------------------------------------------------------------

    72. On August 10, 2009, NERC submitted an informational filing 
setting forth a summary of revised guidelines that NERC intends to use 
in determining the assignment of violation risk factors and violation 
severity levels for Reliability Standards. NERC states that these 
revised guidelines were consistent with Commission's guidelines. On May 
5, 2010, NERC submitted the subject informational filing as a 
supplement to its March 5, 2010 Violation Severity Level Order 
compliance filing.\43\
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    \43\ North American Reliability Corporation, Filing of the North 
American Electric Reliability Corporation regarding the Assignment 
of Violation Risk Factors and Violation Severity Levels, Docket No. 
RR08-4-005 (filed May 5, 2010).
---------------------------------------------------------------------------

NERC Proposal
    73. NERC proposes a complete set of violation severity levels and 
violation risk factors for proposed new Reliability Standards IRO-008-
1, IRO-009-1, and IRO-010-1a. In addition, NERC proposes to apply the 
existing set of violation severity levels and violation risk factors 
assigned to the proposed modified requirements.
    74. NERC states that it developed the violation severity levels for 
the new IRO Reliability Standards before the Commission issued its June 
19, 2008 order on violation severity levels.\44\ NERC also notes that 
the proposed violation severity levels were developed before NERC 
proposed a new methodology for assigning violation severity levels and 
violation risk factors.\45\ As a result, NERC states that some of the 
proposed violation severity levels do not comport with the Commission's 
guidelines on violation severity levels and some do not comport with 
the NERC's revised guidelines. NERC has identified differences and 
commits to propose revisions to the violation severity levels.
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    \44\ Id.
    \45\ NERC, Informational Filing Regarding the Assignment of 
Violation Risk Factors and Violation Severity Levels, Docket Nos. 
RM08-11-000, RR07-9-000, and RR07-10-000, (filed Aug. 10, 2009).
---------------------------------------------------------------------------

NOPR Proposal
    75. The Commission proposes to accept the proposed violation risk 
factors and violation severity levels presented in NERC's petition. In 
addition, we propose to accept NERC's commitment to review the proposed 
violation risk factors and violation severity levels to ensure 
compliance with the Commission's guidelines. Accordingly, we propose to 
direct NERC to submit a compliance filing within six months of the 
effective date of the final rule in this proceeding that would provide 
the results of NERC's review including any modifications necessary to 
comply with the Commission's guidelines on violation risk factors and 
violation severity levels.
    76. The violation risk factors and violation severity levels for 
proposed new Reliability Standards IRO-008-1, IRO-009-1, and IRO-010-
1a, and the proposed modified requirements also would be impacted by 
NERC's revised guidelines for assigning violation severity levels 
currently pending before the Commission in Docket No. RR08-4-005. 
Subject to Commission action on NERC's revised guidelines, NERC may 
need to make additional revisions to the proposed violation risk 
factors and violation severity levels.

III. Information Collection Statement

    77. The Office of Management and Budget (OMB) regulations require 
approval of certain information collection requirements imposed by 
agency rules.\46\ Upon approval of a collection(s) of information, OMB 
will assign an OMB control number and an expiration date. Respondents 
subject to the filing 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. The 
Paperwork Reduction Act (PRA) \47\ requires each federal agency to seek 
and obtain OMB approval before undertaking a collection of information 
directed to ten or more persons, or continuing a collection for which 
OMB approval and validity of the control number are about to 
expire.\48\
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    \46\ 5 CFR 1320.11.
    \47\ 44 U.S.C. 3501-20.
    \48\ 44 U.S.C. 3502(3)(A)(i), 44 U.S.C. 3507(a)(3).
---------------------------------------------------------------------------

    78. The Commission is submitting 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 provided burden estimates, ways to enhance the quality, 
utility, and clarity of the information to be collected, and any 
suggested methods for minimizing the respondent's burden, including the 
use of automated information techniques.
    79. This NOPR proposes to approve three new Reliability Standards, 
IRO-008-1, IRO-009-1 and IRO-010-1a governing reliability coordinator 
analyses, operational actions and data collection, which standards will 
replace parts of the currently-effective Reliability Standards EOP-001-
0, IRO-002-1, IRO-004-1, IRO-005-2, TOP-003-0, TOP-005-1 and TOP-006-1 
approved by the Commission in Order No. 693. Many of the proposed 
requirements are based requirements in currently-effective Reliability 
Standards and match common industry practice. Thus, this proposed 
rulemaking does not impose entirely new burdens on the effected 
entities. With the exception of the addition of Interchange Authority 
as an applicable entity in IRO-010-1a, the currently-effective 
standards EOP-001-0, IRO-002-1, IRO-004-1, IRO-005-2, TOP-003-0, TOP-
005-1 and TOP-006-1 require actions by the same applicable group of 
entities. IRO-010-1a clarifies for balancing authorities, generator 
owners, generator operators, interchange authorities, load-serving 
entities, reliability coordinators, transmission operators, and 
transmission owners shall provide data and information, as specified, 
to the reliability coordinator(s) with which it has a reliability 
relationship.\49\ The requirements of IRO-008-1 and IRO-009-a provide 
clarification from existing requirements, dictating the analysis and 
operational roles of the reliability coordinator.
---------------------------------------------------------------------------

    \49\ Proposed Reliability Standard IRO-010-1a, Requirement R3.
---------------------------------------------------------------------------

    80. Public Reporting Burden: Our estimate below regarding the 
number of respondents is based on the NERC compliance registry as of 
September 28, 2010. According to the NERC compliance registry, there 
are 134 balancing authorities, 824 generator owners, 773 generator 
operators, 61 interchange authorities, 541 load-serving entities, 26 
reliability coordinators, 178 transmission operators, and 332 
transmission owners

[[Page 71624]]

that would be involved in providing information. However, under NERC's 
compliance registration program, entities may be registered for 
multiple functions, and as such there is some duplication of functions 
regarding the number of registered entities that would be required to 
provide information. Given these parameters, the Commission estimates 
that the Public Reporting burden for the requirements contained in the 
NOPR is as follows:

----------------------------------------------------------------------------------------------------------------
                                                                Number of
             Data collection                  Number of          annual           Hours per       Total annual
                                             respondents        responses        respondent           hours
----------------------------------------------------------------------------------------------------------------
FERC-725A
Reliability Coordinators distribution of                26                *1                 8               208
 data specification to entities.........
Balancing Authorities, Generator Owners,             1,501                *1                 8            12,008
 Generator Operators, Interchange
 Authorities, Load-serving Entities,
 Reliability Coordinators, Transmission
 Operators, and Transmission Owners
 reporting data to their Reliability
 Coordinator............................
                                         -----------------------------------------------------------------------
    Total...............................  ................  ................  ................            12,216
----------------------------------------------------------------------------------------------------------------
* As needed.

     Total Annual hours for Collection: (Reporting + 
recordkeeping) = hours.
    Information Collection Costs: The Commission seeks comments on the 
costs to comply with the reporting and recordkeeping burden associated 
with the proposed Reliability Standards. It has projected the average 
annualized cost to be the total annual hours
    Recordkeeping = 12,216 hours @ $120/hour = $1,465,920.
     Total costs = $1,465,920.
     Title: Mandatory Reliability Standards for the Bulk-Power 
System.
     Action: Proposed Collection of Information.
     OMB Control No: 1902-0244.
     Respondents: Business or other for profit, and/or not for 
profit institutions.
     Frequency of Responses: Annually, or as needed.
     Necessity of the Information: This proposed rule would 
approve revised Reliability Standards that create new requirements for 
reliability coordinator responsibilities. The proposed Reliability 
Standards require entities to supply required data and information 
needed by the reliability coordinator.
     Internal review: The Commission has reviewed the 
requirements pertaining to the proposed Reliability Standards for the 
Bulk-Power System and determined that the proposed requirements are 
necessary to meet the statutory provisions of the Energy Policy Act of 
2005. These requirements conform to the Commission's plan for efficient 
information collection, communication and management within the energy 
industry. The Commission has assured itself, by means of internal 
review, that there is specific, objective support for the burden 
estimates associated with the information requirements.
    81. Interested persons may obtain information on the reporting 
requirements by contacting: Federal Energy Regulatory Commission, 888 
First Street, NE., Washington, DC 20426 [Attention: Ellen Brown, Office 
of the Executive Director, Phone: (202) 502-8663, fax: (202) 273-0873, 
e-mail: DataClearance@ferc.gov]. Comments on the requirements of this 
order may also be sent to the Office of Information and Regulatory 
Affairs, Office of Management and Budget, Washington, DC 20503 
[Attention: Desk Officer for the Federal Energy Regulatory Commission]. 
For security reasons, comments should be sent by e-mail to OMB at 
oira_submission@omb.eop.gov. Please reference docket number RM10-15-
000 in your submission.

IV. Environmental Analysis

    82. 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.\50\ The 
actions proposed here fall within the categorical exclusion in the 
Commission's regulations for rules that are clarifying, corrective or 
procedural, for information gathering, analysis, and dissemination.\51\ 
Accordingly, neither an environmental impact statement nor 
environmental assessment is required.
---------------------------------------------------------------------------

    \50\ Order No. 486, Regulations Implementing the National 
Environmental Policy Act, 52 FR 47897 (Dec. 17, 1987), FERC Stats. & 
Regs. ] 30,783 (1987).
    \51\ 18 CFR 380.4(a)(5).
---------------------------------------------------------------------------

V. Regulatory Flexibility Act Certification

    83. The Regulatory Flexibility Act of 1980 (RFA) \52\ generally 
requires a description and analysis of final rules that will have 
significant economic impact on a substantial number of small entities. 
The requirements of this rule would apply primarily to reliability 
coordinators, which do not fall within the definition of small 
entities.\53\ Moreover, the proposed Reliability Standards reflect a 
continuation of existing requirements for reliability coordinators and 
other entities to monitor, analyze, prevent, and mitigate the 
occurrence of operating limit violations on the Bulk-Power System. The 
one exception is the proposed new requirements in Reliability Standard 
IRO-010-1a for interchange authorities, which also do not fall within 
the definition of small entities. Based on the foregoing, the 
Commission certifies that this proposed rule will not have a 
significant impact on a substantial number of small entities. 
Accordingly, no regulatory flexibility analysis is required.
---------------------------------------------------------------------------

    \52\ 5 U.S.C. 601-12.
    \53\ The RFA definition of ``small entity'' refers to the 
definition provided in the Small Business Act (SBA), which defines a 
``small business concern'' as a business that is independently owned 
and operated and that is not dominant in its field of operation. See 
15 U.S.C. 632. According to the SBA, a small electric utility is 
defined as one that has a total electric output of less than four 
million MWh in the preceding year.
---------------------------------------------------------------------------

VI. Comment Procedures

    84. 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 January 24, 2011. Comments must refer to 
Docket No. RM10-15-000, and must include the commenter's name, the 
organization they represent, if applicable, and their address in their 
comments.
    85. 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

[[Page 71625]]

format and not in a scanned format. Commenters filing electronically do 
not need to make a paper filing.
    86. Commenters unable to file comments electronically must mail or 
hand-deliver an original copy of their comments to: Federal Energy 
Regulatory Commission, Secretary of the Commission, 888 First Street, 
NE., Washington, DC 20426. These requirements can be found on the 
Commission's Web site, see, e.g., the ``Quick Reference Guide for Paper 
Submissions,'' available at http://www.ferc.gov/docs-filing/efiling.asp 
or via phone from FERC Online Support at (202) 502-6652 or toll-free at 
1-866-208-3676.
    87. 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.

VII. Document Availability

    88. 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.
    89. 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.
    90. 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 
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.

    By direction of the Commission.
Kimberly D. Bose,
Secretary.
[FR Doc. 2010-29575 Filed 11-23-10; 8:45 am]
BILLING CODE 6717-01-P

