improvements that are not justified by very low probability events.
However, a Reliability Standard should require assessment and
consideration of actions necessary to resolve such events. MidAmerican
recommends that transmission planning Reliability Standards permit
probabilistic approaches to responding to extreme events and events in
Category D of Table 1. While the probability of extreme events often
does not warrant system improvements, it does make sense to require
consideration of mitigating actions or improvements whose cost is
justified by the expected benefits.
    1109. ReliabilityFirst recommends that consideration should be
given to establishing some record of studies and identifying system
weaknesses. CenterPoint states it does not believe that companies
should be required to share planning assessments because it relates
more to open access tariff concerns than reliability. In addition,
sharing assessments would promote the unnecessary disclosure of
critical energy infrastructure information.
iv. Commission Proposal
    1110. The Commission proposes to approve proposed Reliability
Standard TPL-004-0 as a mandatory and enforceable Reliability Standard.
In addition, we propose to direct that NERC develop modifications to
the Reliability Standard, as discussed below.
    1111. The Commission notes that, like Reliability Standards TPL-
001-0 through TPL-003-0, TPL-004-0 requires entities assessing system
performance to cover ``critical system

conditions and study years'' the entity performing the study deems
appropriate, but it does not specify the rationale for determining
critical system conditions and study years. The Commission therefore
proposes that NERC modify TPL-004-0 to require that critical system
conditions be determined in the same manner as discussed above with
regard to TPL-001-0. The Commission also proposes that the results of
these studies be documented to support the selection of critical system
conditions and study years used in assessing system performance. Also
the Commission notes that load models used in system studies have a
significant impact on system performance, particularly as they relate
to the dynamic performance of the system. The Commission proposes that
the documentation of system studies include a description of the load
models used including supporting rationale for their use.
    1112. MidAmerican and MRO agree with Commission staff that
consideration must be given to mitigating actions associated with
impacts of extreme events. MidAmerican proposes using an approach to
take into account probability, impact and value to customers of
reliability. MRO cautions against requiring improvements that cannot be
justified. NERC also states that Reliability Standards should not
require compliance with a high-impact, low probability contingency
imposed on a low probability base case. The Commission agrees that the
Reliability Standard should not require improvements for low
probability events that cannot be justified. However, the Commission
proposes that NERC modify TPL-004-0 to require the identification of
options for reducing the probability or impacts of extreme events that
cause cascading outages. The Commission also proposes that these
options be documented together with a supporting rationale for cases
where such options were not pursued.
    1113. In determining the range of extreme events to be assessed,
staff noted that a number of recent high risk events, such as the
hurricanes affecting the southern United States and the ice storm in
the north, resulted in a greater impact on the Bulk-Power System in
terms of the number of elements forced out of service than events
listed in TPL-004-0. The Commission proposes that the contingency list
of Category D be expanded to include similar events.
    1114. Staff noted that the Reliability Standard does not explicitly
require that the results of assessments be shared with impacted
entities or communicated to operations planning staff and control room
operators. While CenterPoint disfavors such information sharing, we
believe that sharing assessment results would serve an important
reliability purpose as it would provide system operators and impacted
entities with an opportunity to mitigate the identified impact.
However, we agree with CenterPoint that any such requirement should
make clear that that critical energy infrastructure information should
not be unnecessarily disclosed.
    1115. The Commission also notes that TPL-004-0 would be enhanced if
its purpose statement would be tailored to reflect the specific goal of
the standard. In addition, the Commission proposes that each
requirement should correspond to one or more measures and each measure
should correspond to a level of non-compliance.
    1116. While the Commission has identified a number of concerns with
regard to TPL-004-0, this proposed Reliability Standard serves an
important purpose by ensuring that the future Bulk-Power System is
evaluated to assess the risks and consequences of an extreme event
involving the loss of multiple elements. Further, the Requirements set
forth in TPL-004-0 are sufficiently clear and objective to provide
guidance for compliance.
    1117. Accordingly, giving due weight to the technical expertise of
the ERO and with the expectation that the Reliability Standard will
accomplish the purpose represented to the Commission by the ERO and
that it will improve the reliability of the nation's Bulk-Power System,
the Commission proposes to approve Reliability Standard TPL-004-0 as
mandatory and enforceable. In addition, pursuant to section 215(d)(5)
of the FPA and Sec.  39.5(f) of our regulations, the Commission
proposes to direct that NERC submit a modification to TPL-004-0 that:
(1) Requires that critical system conditions be determined in the same
manner as proposed for TPL-001-0; (2) requires the identification of
options for reducing the probability or impacts of extreme events that
cause cascading; (3) requires that, in determining the range of extreme
events to be assessed, the contingency list of Category D be expanded
to include recent events; and (4) tailors the purpose statement to
reflect the specific goal of the Reliability Standard.
g. Regional and Interregional Self-Assessment Reliability Reports (TPL-
005-0)
i. NERC Proposal
    1118. NERC states that proposed Reliability Standard TPL-005-0
ensures that each regional reliability organization conducts
reliability assessments of its existing and planned regional bulk
electric system annually by requiring the regional reliability
organization to assess and document the performance of its power system
for the current year, the next five years, and to analyze trends for
the longer-term planning horizons.
ii. Staff Preliminary Assessment
    1119. Staff noted that the Reliability Standard identifies the
regional reliability organization as the applicable entity.
iii. Comments
    1120. NYSRC recommends that this proposed Reliability Standard be
withdrawn, as it anticipates that regional reliability organizations
will develop regional transmission planning standards due to regional
differences specific to their region. CenterPoint also suggests that
the proposed Reliability Standard be eliminated.
    1121. ISO/RTO Council states that the term and extent of
assessment, as well as the study years, are not appropriately defined;
the process for determining load levels needs to be standardized; and
local area networks and system adjustments need to be specifically
defined.
iv. Commission Proposal
    1122. Consistent with our discussion in the Common Issues section
above, the Commission will not propose any action on TPL-005-0, as it
applies only to regional reliability organizations. Accordingly, the
Reliability Standard will remain pending at the Commission. The
Commission believes that, in the long-run, the Regional Entities should
be responsible for conducting reliability assessments of the existing
and planned regional system. However, during the current period of
transition, the regional reliability organizations should continue to
perform this role as they have in the past.
    1123. In addition, the Commission agrees with the ISO/RTO Council
regarding the shortcomings in the Reliability Standard it has
identified and proposes that NERC address these issues in the revision
to the Reliability Standard.

h. Assessment Data From Regional Reliability Organizations (TPL-006-0)
i. NERC Proposal
    1124. NERC states that proposed Reliability Standard TPL-006-0
ensures that the data necessary to conduct reliability assessments is
available by requiring the regional reliability organization to provide
NERC with Bulk-Power System data, reports, demand and energy forecasts,
and other information necessary to assess reliability and compliance
with NERC Reliability Standards and relevant regional planning
criteria.
ii. Staff Preliminary Assessment
    1125. Staff noted that the Reliability Standard identifies the
regional reliability organization as the applicable entity.
iii. Comments
    1126. NYSRC recommends that this Reliability Standard be withdrawn
because it anticipates that regional reliability organizations will
develop regional transmission planning standards based on regional
differences specific to their regions. CenterPoint also suggests
eliminating this Reliability Standard.
    1127. ISO/RTO Council suggests that, for the ERO to be successful
at assessing overall reliability, it must identify what data and
reports it needs to review in order to ensure that adequate planning is
being conducted.
iv. Commission Proposal
    1128. Consistent with our discussion in the Common Issues section
above, the Commission will not propose any action on TPL-006-0, as it
applies only to regional reliability organizations. Accordingly, the
Reliability Standard will remain pending at the Commission. The
Commission believes that, in the long-run, the Regional Entities should
be responsible for providing NERC with Bulk-Power System data, reports,
demand and energy forecasts, and other information necessary to assess
reliability and compliance with NERC Reliability Standards and relevant
regional planning criteria. However, during the current period of
transition, the regional reliability organizations should continue to
perform this role as they have in the past.
13. VAR: Voltage and Reactive Control
a. Overview
    1129. The Version 0 Voltage and Reactive Control (VAR) Reliability
Standard VAR-001-0 is intended to maintain Bulk-Power System facilities
within voltage and reactive power limits, thereby protecting
transmission, generation, distribution, and customer equipment and the
reliable operation of the Interconnection. The Voltage and Reactive
Control group of Reliability Standards is intended to replace the
existing VAR-001-0 and consists of two proposed Reliability Standards,
VAR-001-1 and VAR-002-1, with new Requirements. These two new proposed
Reliability Standards have been submitted by NERC as part of the August
28, 2006 Supplemental Filing for Commission review. Because there is
significant overlap between VAR-001-0 and version 1 Reliability
Standards, the Commission will address them collectively below, giving
due consideration to the new Requirements in addressing the proposed
disposition of VAR-001-1 and VAR-002-1.
b. Voltage and Reactive Control (VAR-001-1 and VAR-002-1)
i. NERC Proposal
    1130. NERC explains that VAR-001-1 requires the transmission
operator to monitor and control voltage levels, reactive flows, and
reactive resources, in order to keep these parameters within their
reliability limits. Further, it requires a generator operator to
provide critical operating data to its transmission operator, and to
maintain generator field excitation at proper levels. The proposed
Reliability Standard would apply to transmission operators, generator
operators and purchasing-selling entities.
    1131. In its August 28, 2006 Supplemental Filing, NERC indicates
that VAR-001-1 includes three new Requirements, designated R3, R4 and
R11, which apply to transmission operators. Requirement R9 from VAR-
001-0, which applies to generator operators, is now replaced with five
Requirements in VAR-002-1. Both Reliability Standards include Measures
and Levels of Non-Compliance.
ii. Staff Preliminary Assessment
    1132. The VAR Reliability Standard requires each transmission owner
to ``acquire sufficient reactive resources within its areas to protect
the voltage levels under normal and Contingency conditions'' and
``maintain system and Interconnection voltages within established
limits.'' \333\ The Staff Preliminary Assessment stated that these
Requirements may not be sufficient to assure reliable operation when
operating power systems under conditions that make them vulnerable to
voltage collapse.\334\ Staff noted that voltage instability has been a
common causal factor in major power outages worldwide and voltage
magnitudes alone are poor indicators of voltage stability.
---------------------------------------------------------------------------

    \333\ See VAR-001-1, Requirements R2 and R8.
    \334\ Staff Preliminary Assessment at 118 (although the Staff
Preliminary Assessment addresses concerns regarding the version 0
VAR Reliability Standard, many of these same concerns apply to the
version 1 VAR Reliability Standards as well).
---------------------------------------------------------------------------

    1133. The Staff Preliminary Assessment explained that the proposed
Reliability Standard does not require applicable entities to perform
operations planning studies that would identify the minimum permissible
pre-contingency voltage levels and reactive power reserves to ensure
stable post-contingency voltages. In addition, the standard does not
require similar voltage stability assessments to be carried out
periodically during real-time operations so that system operators can
continuously respond to changing system conditions.
    1134. Because voltage and reactive control is an integral part of
Interconnection Reliability Operating Limits and voltage collapse can
result in widespread cascading outages, staff expressed concern that
reliable operation of the Bulk-Power System requires that reliability
coordinators be authorized to direct and coordinate voltage and
reactive control among operating entities in an Interconnection, and
accordingly this standard should also apply to reliability
coordinators. Similarly, staff noted that Requirement R5, which
requires each purchasing-selling entity to arrange for reactive
resources to satisfy its reactive requirements identified by its
transmission service provider, does not currently apply to load-serving
entities, even though a load-serving entity is responsible for
significantly more load than a purchasing-selling entity. Therefore,
the Reliability Standard should also apply to load-serving entities.
    1135. Finally, staff noted that the proposed reliability standard
does not address Recommendation No. 23 of the Blackout Report,
``[s]trengthen reactive power and voltage control practices in all NERC
regions.'' \335\ However, staff noted that NERC did respond to the
recommendation by establishing the Transmission Issues Subcommittee
(TIS) which completed an evaluation of reactive power planning and
voltage control practices.
---------------------------------------------------------------------------

    \335\ Blackout Report at 160.
---------------------------------------------------------------------------

iii. Comments
    1136. NERC states that the proposed reactive power and voltage
control

Reliability Standard is adequate and necessary to protect the
reliability of the Bulk-Power System. It points out that, in addition
to the proposed Reliability Standard, a number of other Version 0
standards in the IRO, TOP, and TPL series address reactive power and
voltage control requirements and suggests that the proposed Reliability
Standards should be viewed in their entirety in assessing their
adequacy.
    1137. Nonetheless, NERC states that staff is correct that
additional consideration regarding the development of the Reliability
Standard related to reactive power and voltage control, reactive
reserves, and the related subject of under-voltage load shedding is
required. It explains that, in response to the Blackout Report
recommendations related to reactive power and voltage control, the NERC
Planning Committee prepared a report titled ``Evaluation of Reactive
Power Planning and Voltage Control Practices,'' which was accepted by
the NERC board of Trustees in May 2005. NERC states that it is
committed to developing, as a high priority, new Reliability Standards
that will incorporate the recommendations of the Planning Committee's
report. NERC does not agree with the Staff Preliminary Assessment
concerning the lack of applicability of the standard to load-serving
entities. NERC contends that a load-serving entity that purchases
outside resources to serve its load and uses transmission service to
import that energy acts as a purchasing-selling entity and must arrange
reactive support services pursuant to VAR-001-0.
    1138. ReliabilityFirst, on the other hand, agrees with staff's
concern that the proposed Reliability Standard should apply to load-
serving entities and reliability coordinators. As a general matter and
in the specific context of the proposed Reliability Standard,
ReliabilityFirst states the work by NERC's drafting team to develop
missing compliance elements must be expedited. In addressing staff's
primary issues with this standard, ReliabilityFirst states that
acceptable variations in voltage used by operating personnel should be
minimized by the development of more defined terms.
iv. Commission Proposal
    1139. The Commission proposes to approve VAR-001-1 as mandatory and
enforceable. In addition, we propose to direct that NERC develop
modifications to the Reliability Standard, as discussed below.
    1140. As explained in the Staff Preliminary Assessment, the
proposed Reliability Standard requires a transmission owner to
``acquire sufficient reactive resources within its area to protect the
voltage levels under normal and Contingency conditions'' \336\ and
``maintain system and Interconnection voltages within established
limits.'' \337\ In the Commission's view, technical requirements
containing terms such as ``established limits'' or ``sufficient
reactive resources'' are not definitive enough to address voltage
instability and to ensure reliable operations.\338\ As an example of
the Commission's concept of a more effective requirement, NERC should
consider WECC's Reliability Criteria, which contain specific and
definitive technical requirements on voltage and margin
application.\339\ The Commission's view is also consistent with the
NERC Transmission Issue Subcommittee's findings in its ``Evaluation of
Reactive Power Planning and Voltage Control Practices.'' \340\ The
Commission notes that VAR-001-1, while adding three new Requirements
that apply to transmission operators regarding voltage and reactive
control, still lacks the specific and technical Requirements on voltage
and margin application to prevent voltage instability.\341\ Therefore,
the Commission proposes directing NERC to modify VAR-001-1 to include
more detailed and definitive requirements on ``established limits'' and
``sufficient reactive resources'' to prevent voltage instability and to
ensure reliable operations. These requirements for ensuring voltage
stability shall be included in operations planning studies and real-
time assessment in addition to real time operation.
---------------------------------------------------------------------------

    \336\ VAR-001-1, Requirement R2.
    \337\ VAR-001-1, Requirement R8.
    \338\ See Staff Preliminary Assessment at 118, citing Blackout
Report at 36 (``voltage magnitude alone is a poor indicator of
voltage stability'').
    \339\ WECC's Reliability Criteria at 32 states ``For transfer
paths, post-transient voltage stability is required with the path
modeled at a minimum of 105% of the path rating (or Operational
Transfer Capability) for system normal conditions (Category A) and
for single contingencies (Category B). For multiple contingencies
(Category C), post-transient voltage stability is required with the
path modeled at a minimum of 102.5% of the path rating (or
Operational Transfer Capability).
    \340\ See http://www.NERC.com/pub/sys/all_updl/pc/tis/TIS_Reactive_Recom7a_BOTapprvd_050305
.

    \341\ VAR-001-1 Requirement R3 requires transmission owners to
specify criteria that exempt generators from complying with
Requirement R4. Requirement R4 requires transmission owners to
specify a voltage or reactive power schedule to be maintained by
generators. Requirement R11 requires transmission operators to
provide documentation to generator owners on necessary step-up
transformer tap changes.
---------------------------------------------------------------------------

    1141. While real-time operations are covered by other standards,
the requirement to perform periodic voltage stability analysis in real-
time operations is not directly addressed. Because of its importance to
Bulk-Power System reliability, as discussed in section ii above, the
Commission proposes that it be directly addressed in VAR-001-1.
    1142. Section 215(b) of the FPA provides that users, owners and
operators of the Bulk-Power System must comply with a Commission-
approved Reliability Standard. As discussed above, NERC's proposed
Reliability Standards identify the entities to which a particular
Reliability Standard would apply according to the NERC Functional
Model. According to NERC's proposal, VAR-001-1 would apply to
transmission operators and purchasing-selling entities. In Requirement
R5, purchasing-selling entities are required to arrange for reactive
resources to satisfy their reactive requirements as identified by their
transmission service provider. Because purchasing-selling entities are
either self-providing or purchasing the reactive resources, they are
clearly users of the Bulk-Power System.
    1143. The Commission believes that NERC's proposed applicability
provision in VAR-001-1, in terms of the Functional Model, should be
expanded to include ``reliability coordinators'' and ``load-serving
entities.'' According to NERC's petition, ``load-serving entities'' are
energy providers for end use customers, and NERC's functional model
defines the load serving function as responsible for ``secur[ing]
energy and transmission service (and related Interconnected Operations
Services) to serve the end-use customer.'' \342\ Reliability
coordinators and load-serving entities are operators and users of the
bulk-power system respectively, and should be included in the
applicability of this standard as discussed in more detail below.
---------------------------------------------------------------------------

    \342\ NERC glossary at 9.
---------------------------------------------------------------------------

    1144. In a complex power grid such as the one which exists in North
America, reliable operations can only be ensured by coordinated efforts
from all operating entities in long term planning, operational planning
and real time operations. To that end, the Staff Preliminary Assessment
recommended (and ReliabilityFirst concurred) that the applicability of
this proposed Reliability Standard extend to both reliability
coordinators and load-serving entities. Since reliability coordinators
are the highest level of authority overseeing the reliability of the
Bulk-Power System, it is important to include them as an applicable
entity to maintain adequate voltage and reactive resources. As for
load-serving entities, NERC states that

VAR-001-0 (and NERC's statement applies equally to VAR-001-1) is
indirectly applicable to a load-serving entity in its role as a
purchasing-selling entity to the extent that it purchases outside
resources to serve its load and uses transmission service to import
that energy. Although the Commission agrees with this statement to the
extent that a load-serving entity is purchasing point-to-point
transmission service to serve its load, it is not clear that a load-
serving entity would become a purchasing-selling entity when utilizing
network service to meet its load obligations. The Commission is
interested in comments concerning NERC's assertion that all load
serving entities are also purchasing-selling entities.
    1145. We propose directing NERC to add reliability coordinators and
load-serving entities to the existing list of applicable entities for
VAR-001-1 for added clarity. VAR-001-1 recognizes that energy purchases
of purchasing-selling entities can increase reactive power consumption
on the Bulk-Power System and that they must supply what they consume.
Load-serving entities also consume reactive power. We note that in many
cases load response and load-side investment can reduce the need for
reactive power capability in the system.\343\ Therefore, we propose to
include controllable load among the reactive resources to satisfy
reactive requirements.
---------------------------------------------------------------------------

    \343\ See Principles of Efficient and Reliable Reactive Power
Supply and Consumption: FERC Staff Report (2005).
---------------------------------------------------------------------------

    1146. We are also interested in comments on the acceptable ranges
of net power factor range at the interface that the load serving
entities receive service from the Bulk-Power System during normal and
extreme load conditions.
    1147. While the Commission has identified a number of concerns with
regard to VAR-001-1, we believe that the proposal serves an important
purpose in requiring users, owners and operators of the Bulk-Power
System to maintain facilities within voltage limits. The Commission
believes it is important for NERC to include Requirements which contain
added specificity; and additional Requirements to perform voltage
stability assessments during real-time operations. Nonetheless, the
proposed requirements set forth in VAR-001-1 are sufficiently clear and
objective to provide guidance for compliance.
    1148. Accordingly, giving due weight to the technical expertise of
the ERO and with the expectation that the Reliability Standard will
accomplish the purpose represented to the Commission by the ERO and
that it will improve the reliability of the nation's Bulk-Power System,
the Commission proposes to approve Reliability Standard VAR-001-1 as
mandatory and enforceable. In addition, pursuant to section 215(d)(5)
of the FPA and Sec.  39.5(f) of our regulations, the Commission
proposes to direct that NERC submit a modification to VAR-001-1 that:
(1) Includes detailed and definitive requirements on ``established
limits'' and ``sufficient reactive resources'' as discussed above, and
identifies acceptable margins above the voltage instability points; (2)
includes Requirements to perform voltage stability assessments
periodically during real-time operations; and (3) expands the
applicability to include reliability coordinators and load-serving
entities.
    1149. The Commission commends NERC and industry for their efforts
in expanding on Requirement R9, which applied to generator operators in
VAR-001-0, and making it into several detailed Requirements in VAR-002-
1, which apply to generator operators and generator owners, complete
with Measures and Levels of Non-Compliance to ensure appropriate
generation operation to maintain network voltage schedules.
    1150. Accordingly, the Commission believes that Reliability
Standard VAR-002-1 is just, reasonable, not unduly discriminatory or
preferential, and in the public interest; and proposes to approve it as
mandatory and enforceable.
14. Glossary of Terms Used in Reliability Standards
a. NERC Proposal
    1151. In its petition, NERC submitted, and requested approval of
the Glossary of Terms Used in Reliability Standards. NERC states that
the glossary, which defines terms used in Reliability Standards,
initially became effective on April 1, 2005. The glossary is updated
whenever a new or revised Reliability Standards is approved that
includes a new term or definition. The glossary may also be approved by
a separate action using NERC's Reliability Standards development
process. NERC updated the glossary in its August 28, 2006 Supplemental
Filing.
b. Staff Preliminary Assessment
    1152. While staff did not globally address the NERC glossary, it
did express concern regarding the definition of bulk electric system in
the glossary. Staff stated that differences between the Bulk-Power
System in section 215 of the FPA and the NERC definition of bulk
electric system could create a discrepancy that results in reliability
``gaps.'' \344\ Further, in its discussion of planning (TPL)
Reliability Standards, staff expressed concern regarding the statutory
definition of Reliable Operation as it would impact the contingencies
to be considered in setting system performance expectations set forth
in the TPL standard.
---------------------------------------------------------------------------

    \344\ Staff Preliminary Assessment at 25-26.
---------------------------------------------------------------------------

c. Comments
    1153. Commenters note that some glossary terms are not consistent
with the definition for those same terms in the ERO's Rules of
Procedure. They point to the definition of regional reliability
organization and load serving entity as examples. Comments on the term
Bulk-Power System and Reliable Operation are included with the TPL
chapter.
d. Commission Proposal
    1154. The Commission believes that the NERC glossary is an
important supplement to understanding the mandatory and enforceable
Reliability Standards. While we are generally satisfied with the NERC
glossary, we believe that it is appropriate that NERC modify the
glossary to include terms defined in section 215(a) of the FPA.
Further, in the general Applicability discussion we explained our
specific concerns regarding potential differences between the statutory
term Bulk-Power System and the NERC term bulk electric system and how
to bring consistency between the two terms. Further, in our discussion
of general issues concerning the communication (COM) Reliability
Standards, we identified specific concerns regarding the definitions of
transmission operator and generator operator. We propose to direct that
NERC modify the glossary to reflect these concerns.
    1155. With regard to commenters concerns regarding the consistency
of definitions between the glossary and the ERO Rules of Procedure, we
believe that the ERO documents should be consistent in their definition
of a specific term. However, we will leave it to the ERO's discretion
whether the glossary or the Rules of Procedure should be modified to
assure consistency in the definition of any particular term.
    1156. Accordingly, the Commission proposes to approve the Glossary
of Terms Used in Reliability Standards. In addition, we propose to
direct that NERC submit, a modification to the

glossary that: (1) Includes the statutory definitions of Bulk-Power
System, Reliable Operation, Reliability Standard, as set forth in
section 215 (a); (2) modifies the definitions of ``transmission
operator'' and ``generator operator'' to include aspects unique to ISO/
RTO and pooled resource organizations; (3) modifies the definition of
``bulk electric system'' consistent with our discussion in the Common
Issues section above; and (4) modifies the definition of terms
concerning reserves (such as operating reserves) to include demand side
management, including controllable load.

IV. Information Collection Statement

    1157. The Office of Management and Budget (OMB) regulations require
that OMB approve certain reporting and recordkeeping (collections of
information) imposed by an agency.\345\ The information contained here
is also subject to review under Section 3507(d) of the Paperwork
Reduction Act of 1995.\346\ As stated above, these 107 proposed
Reliability Standards--of which the Commission proposes to approve 83
in a final rule--make up the current NERC standards that the electric
industry currently is expected to comply with on a voluntary basis.
Therefore, in proposing to adopt the Reliability Standards, the
Commission would adopt reporting requirements that have been
implemented on a voluntary basis for many years in most instances.
Because the reporting requirements are usual and customary practices in
the industry, and respondents incur the time and financial resources in
the course of their regular activity, the transition from voluntary to
mandatory Reliability Standards effected by this Proposed Rule will not
increase the reporting burden nor impose any additional information
collection requirements.
---------------------------------------------------------------------------

    \345\ 5 CFR 1320.11.
    \346\ 44 U.S.C. 3507(d).
---------------------------------------------------------------------------

    1158. However, we also recognize that there may be some smaller
entities such as municipal utilities, cooperatives and small generators
that may not have been members of NERC and may not have been
participants in NERC's voluntary standards program. For such entities,
compliance with the proposed mandatory Reliability Standards will
include compliance with reporting requirements for the first time.
    1159. It is difficult to determine exactly how many entities fall
into this category. First, as discussed above with regard to
applicability issues, not every proposed Reliability Standard would
apply to every user, owner or operator of the Bulk-Power System, and
each proposed Reliability Standard contains its own set of reporting
requirements. For example, only 24 proposed Reliability Standards would
apply to generators, which contain 142 reporting requirements.
    1160. Further, as discussed in greater detail below with regard to
small business flexibility, NERC has indicated that it will propose
specific limits on the applicability of Reliability Standards to small
entities that do not have a material impact on the Bulk-Power System.
While we do not pre-judge this proposal, we note that Commission
acceptance of such a proposal could also have a significant impact on
the reporting burden of small entities that have not previously
complied with the NERC standards on a voluntary basis.
    1161. In addition, some small entities may join together in Joint
Action Agencies or other such organizations that will be responsible
for certain aspects of their members' compliance with mandatory
Reliability Standards. Such umbrella organizations may lessen the
reporting burden of individual users, owners and operators.
Accordingly, the reporting burden estimate below, while based on the
Commission's best information, is subject to numerous variables.
Although there is considerable uncertainty regarding the number of
entities or the burden on those entities for which compliance with
reliability standards will be a new exercise and not a customary
practice, the Commission provides below what it believes to be a
reasonable estimate based on available information.

                                             Public Reporting Burden
----------------------------------------------------------------------------------------------------------------
                                                 Number of        Number of     Number of hours    Total annual
               Data collection                  respondents       responses      per  response        hours
----------------------------------------------------------------------------------------------------------------
FERC-725A...................................           2,000                1              100          200,000
----------------------------------------------------------------------------------------------------------------

    Information Collection Costs: The Commission seeks comments on the
costs on complying with these requirements. It has projected the
average annualized cost to be the following:
    1162. Title: Bulk Power System Mandatory Reliability Standards.
    1163. Action: Proposed Collection.
    1164. OMB Control No. To be Determined.
    1165. Respondents: Businesses or other for profit; not for profit
institutions.
    1166. Frequency of Responses: On Occasion.
    1167. Necessity of the Information: This proposed rule implements
section 215(d)(2) of the FPA, which provides that the Commission may
approve a proposed Reliability Standard if it determines that the
proposal is just, reasonable, not unduly discriminatory or
preferential, and in the public interest.
    1168. Internal Review: The Commission has reviewed the proposed
reliability standards and made a determination that these requirements
are necessary to implement section 215 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 to assure itself, by means of internal
review, that there is specific, objective support for the burden
estimates associated with the information requirements.
    1169. Interested person may obtain information on the reporting
requirements by contacting the following: Federal Energy Regulatory
Commission, 888 First Street, NE., Washington, DC 20426 [Attention:
Michael Miller, Office of the Executive Director, Phone: (202) 502-
8415, fax:<PHONE_NUMBER>, e-mail<EMAIL_ADDRESS>    1170. For submitting comments concerning the collection(s) of
information and the associated burden estimate(s), please send your
comments to the contact listed above and to the Office of Information
and Regulatory Affairs, Office of Information and Regulatory Affairs,
Washington, DC

20503 [Attention: Desk Officer for the Federal Energy Regulatory
Commission, phone<PHONE_NUMBER>, fax:<PHONE_NUMBER>, e-mail:
<EMAIL_ADDRESS>

V. Environmental Analysis

    1171. 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.\347\ 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.\348\
---------------------------------------------------------------------------

    \347\ Regulations Implementing the National Environmental Policy
Act, Order No. 486, 52 FR 47,897 (Dec. 17, 1987), FERC Stats. &
Regs., Regulations Preambles 1986-1990 ] 30,783 (1987).
    \348\ 18 CFR 380.4(a)(5).
---------------------------------------------------------------------------

VI. Regulatory Flexibility Act Certification

    1172. The Regulatory Flexibility Act of 1980 (RFA) \349\ requires
that a rulemaking contain either a description and analysis of the
effect that the proposed rule will have on small entities or a
certification that the rule will not have a 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 and sends the
certification to the Chief Counsel for Advocacy of the Small Business
Administration (SBA). The SBA's Office of Size Standards develops the
numerical definition of a small business. (See 13 CFR 121.201.) For
electric utilities, 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 12 months did not exceed four million megawatt hours.
---------------------------------------------------------------------------

    \349\ 5 U.S.C. 601-12.
---------------------------------------------------------------------------

    1173. Section 215(b) of the FPA requires all users, owners and
operators of the Bulk-Power System to comply with Commission-approved
Reliability Standards. As discussed above, each proposed Reliability
Standard submitted for approval by NERC applies to some subset of
users, owners and operators. Each proposed Reliability Standard
includes an ``applicability'' statement that identifies the functional
classes of entities responsible for compliance. Such functional classes
include reliability coordinators, balancing authorities, transmission
operators, transmission owners, generator operators, generator owners,
interchange authorities, transmission service providers, market
operators, planning authorities, transmission planners, resource
planners, load-serving entities, purchasing-selling entities, and
distribution providers.\350\
---------------------------------------------------------------------------

    \350\ See NERC Petition at 9-10.
---------------------------------------------------------------------------

    1174. As explained by NERC, a generator operator, for example,
could include any entity that operates a generator interconnected to
the grid, be it a large unit in excess of 1,000 MW or a small generator
of one MW or less. NERC states that to ensure that Reliability
Standards are applied cost effectively and that the applicability of
Reliability Standards is focused on entities having a material impact
on Bulk-Power System reliability; it will begin providing greater
specificity in the applicability section of a Reliability
Standard.\351\ For example, a Reliability Standard may identify
limitations on applicability based on electric facility
characteristics, such as generators with a minimum nameplate rating or
a transmission facility energized at a specified kV level or
greater.\352\ NERC plans to establish a set of guidelines to address
this matter.
---------------------------------------------------------------------------

    \351\ Id. at 81-82.
    \352\ Id. at 10.
---------------------------------------------------------------------------

    1175. The Commission believes that the proposed Reliability
Standards may cause some small entities to experience significant
economic impact. While the Commission is mindful of the possible impact
on small entities, the Commission is also concerned that Bulk-Power
System reliability not be compromised based on an unwillingness of
entities, large or small, to incur reasonable expenditures necessary to
preserve such reliability. As we explained in Order No. 672:

    A proposed Reliability Standard may take into account the size
of the entity that must comply with the Reliability Standard and the
cost to those entities of implementing the proposed Reliability
Standard. However, the ERO should not propose a ``lowest common
denominator'' Reliability Standard that would achieve less than
excellence in operating system reliability solely to protect against
reasonable expenses for supporting this vital national
infrastructure. For example, a small owner or operator of the Bulk
Power-System must bear the cost of complying with each Reliability
Standard that applies to it.\353\

    \353\ Order No. 672 at P 330.
---------------------------------------------------------------------------

    1176. While we cannot rule on the merits until a specific proposal
has been submitted, we believe that reasonable limits on applicability
based on size may be an acceptable alternative to lessen the economic
impact on the proposed rule on small entities.\354\ We emphasize,
however, that any such limits must not weaken Bulk-Power System
reliability.
---------------------------------------------------------------------------

    \354\ See, discussion of Applicability to Small Entities,
section III.B.3. above.
---------------------------------------------------------------------------

VII. Comment Procedures

    1177. 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 2, 2007. Comments must
refer to Docket No. RM06-16-000, and must include the commenter's name,
the organization represented, if applicable, and the commenter's
address. Comments may be filed either in electronic or paper format.
    1178. Comments may 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 and commenters may attach
additional files with supporting information in certain other file
formats. Commenters filing electronically do not need to make a paper
filing. Commenters that are not able to file comments electronically
must send an original and fourteen (14) copies of their comments to:
Federal Energy Regulatory Commission, Office of the Secretary, 888
First Street, NE., Washington, DC 20426.

VIII. Document Availability

    1179. 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.
    1180. From the Commission's Home Page on the Internet, this
information is available in the Commission's document management
system, 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.
    1181. User assistance is available for eLibrary and the FERC's Web
site during normal business hours. For assistance, please contact FERC
Online Support at

1-866-208-3676 (toll free) or<PHONE_NUMBER> (e-mail at
FERCOnlineSupport@FERC.gov), or the Public Reference Room at 202-502-

8371, TTY<PHONE_NUMBER> (e-mail at public.referenceroom@ferc.gov).

List of Subjects in 18 CFR Part 40

    Electric power, Reporting and recordkeeping requirements.

    By direction of the Commission.
Magalie R. Salas,
Secretary.

    In consideration of the foregoing, the Commission proposes to amend
Chapter I, Title 18, Code of Federal Regulations, by adding part 40 to
read as follows:

PART 40--MANDATORY RELIABILITY STANDARDS FOR THE BULK-POWER SYSTEM

Sec.
40.1 Applicability.
40.2 Mandatory Reliability Standards.
40.3 Availability of Reliability Standards.

    Authority: 16 U.S.C. 824o.

Sec.  40.1  Applicability.

    (a) This part applies to all users, owners and operators of the
Bulk-Power System within the United States (other than Alaska or
Hawaii), including, but not limited to, entities described in section
201(f) of the Federal Power Act.
    (b) Each Reliability Standard made effective by Sec.  40.2 must
identify the subset of users, owners and operators of the Bulk-Power
System to which a particular Reliability Standard applies.

Sec.  40.2  Mandatory Reliability Standards.

    (a) Each applicable user, owner or operator of the Bulk-Power
System must comply with Commission-approved Reliability Standards
developed by the North American Electric Reliability Corporation which
can be obtained from the Commission's Public Reference Room at 888
First Street, NE., Room 2A, Washington, DC 20426.
    (b) A proposed modification to a Reliability Standard proposed to
become effective pursuant to Sec.  39.5 of this Chapter will not be
effective until approved by the Commission.

Sec.  40.3  Availability of Reliability Standards.

    The Electric Reliability Organization must make each effective
Reliability Standard available on its Internet Web site.

    Note: The following appendices will not be published in the Code
of Federal Regulations.

  Appendix A.--Proposed Disposition of Standards, Glossary and Regional
                               Differences
------------------------------------------------------------------------
                                                            Proposed
     Reliability standard               Title             disposition
------------------------------------------------------------------------
BAL-001-0....................  Real Power Balancing    Approve.
                                Control Performance.
BAL-002-0....................  Disturbance Control     Approve; direct
                                Performance.            modification.
BAL-003-0....................  Frequency Response and  Approve; direct
                                Bias.                   modification.
BAL-004-0....................  Time Error Correction.  Approve; direct
                                                        modification.
BAL-005-0....................  Automatic Generation    Approve; direct
                                Control.                modification.
BAL-006-1....................  Inadvertent             Approve; direct
                                Interchange.            modification.
CIP-001-0....................  Sabotage Reporting....  Approve; direct
                                                        modification.
COM-001-0....................  Telecommunications....  Approve; direct
                                                        modification.
COM-002-1....................  Communications and      Approve; direct
                                Coordination.           modification.
EOP-001-0....................  Emergency Operations    Approve; direct
                                Planning.               modification.
EOP-002-1....................  Capacity and Energy     Approve; direct
                                Emergencies.            modification.
EOP-003-0....................  Load Shedding Plans...  Approve; direct
                                                        modification.
EOP-004-0....................  Disturbance Reporting.  Approve; direct
                                                        modification.
EOP-005-1....................  System Restoration      Approve; direct
                                Plans.                  modification.
EOP-006-0....................  Reliability             Approve; direct
                                Coordination--System    modification.
                                Restoration.
EOP-007-0....................  Establish, Maintain,    Pending.
                                and Document a
                                Regional Blackstart
                                Capability Plan.
EOP-008-0....................  Plans for Loss of       Approve; direct
                                Control Center          modification.
                                Functionality.
EOP-009-0....................  Documentation of        Approve.
                                Blackstart Generating
                                Unit Test Results.
FAC-001-0....................  Facility Connection     Approve.
                                Requirements.
FAC-002-0....................  Coordination of Plans   Approve; direct
                                for New Facilities.     modification.
FAC-003-1....................  Transmission            Approve; direct
                                Vegetation Management   modification.
                                Program.
FAC-004-0....................  Methodologies for       Withdrawn.
                                Determining
                                Electrical Facility
                                Ratings.
FAC-005-0....................  Electrical Facility     Withdrawn.
                                Ratings for System
                                Modeling.
FAC-008-1....................  Facility Ratings        Approve; direct
                                Methodology.            modification.
FAC-009-1....................  Establish and           Approve.
                                Communicate Facility
                                Ratings.
FAC-012-1....................  Transfer Capabilities   Pending.
                                Methodology.
FAC-013-1....................  Establish and           Approve; direct
                                Communicate Transfer    modification.
                                Capabilities.
INT-001-1....................  Interchange             Approve; direct
                                Transaction Tagging.    modification.
INT-002-0....................  Interchange             Withdrawn.
                                Transaction Tag
                                Communication and
                                Assessment.
INT-003-1....................  Interchange             Approve; direct
                                Transaction             modification.
                                Implementation.
INT-004-1....................  Interchange             Approve; direct
                                Transaction             modification.
                                Modifications.
INT-005-1....................  Interchange Authority   Approve; direct
                                Distributes Arranged    modification.
                                Interchange.
INT-006-1....................  Response to             Approve; direct
                                Interchange Authority.  modification.
INT-007-1....................  Interchange             Approve.
                                Confirmation.
INT-008-1....................  Interchange Authority   Approve.
                                Distributes Status.
INT-009-1....................  Implementation of       Approve.
                                Interchange.
INT-010-1....................  Interchange             Approve.
                                Coordination
                                Exceptions.
IRO-001-0....................  Reliability             Approve; direct
                                Coordination--Respons   modification.
                                ibilities and
                                Authorities.
IRO-002-0....................  Reliability             Approve; direct
                                Coordination--Facilit   modification.
                                ies.
IRO-003-1....................  Reliability             Approve; direct
                                Coordination--Wide      modification.
                                Area View.
IRO-004-1....................  Reliability             Approve; direct
                                Coordination--Operati   modification.
                                ons Planning.
IRO-005-1....................  Reliability             Approve; direct
                                Coordination--Current   modification.
                                Day Operations.
IRO-006-3....................  Reliability             Approve; direct
                                Coordination--Transmi   modification.
                                ssion Loading Relief.
IRO-014-1....................  Procedures, Processes,  Approve.
                                or Plans to Support
                                Coordination Between
                                Reliability
                                Coordinators.

IRO-015-1....................  Notifications and       Approve.
                                Information Exchange
                                Between Reliability
                                Coordinators.
IRO-016-1....................  Coordination of Real-   Approve.
                                time Activities
                                Between Reliability
                                Coordinators.
MOD-001-0....................  Documentation of TTC    Pending.
                                and ATC Calculation
                                Methodologies.
MOD-002-0....................  Review of TTC and ATC   Pending.
                                Calculations and
                                Results.
MOD-003-0....................  Procedure for Input on  Pending.
                                TTC and ATC
                                Methodologies and
                                Values.
MOD-004-0....................  Documentation of        Pending.
                                Regional CBM
                                Methodologies.
MOD-005-0....................  Procedure for           Pending.
                                Verifying CBM Values.
MOD-006-0....................  Procedures for Use of   Approve; direct
                                CBM Values.             modification.
MOD-007-0....................  Documentation of the    Approve; direct
                                Use of CBM.             modification.
MOD-008-0....................  Documentation and       Pending.
                                Content of Each
                                Regional TRM
                                Methodology.
MOD-009-0....................  Procedure for           Pending.
                                Verifying TRM Values.
MOD-010-0....................  Steady-State Data for   Approve; direct
                                Transmission System     modification.
                                Modeling and
                                Simulation.
MOD-011-0....................  Regional Steady-State   Pending.
                                Data Requirements and
                                Reporting Procedures.
MOD-012-0....................  Dynamics Data for       Approve; direct
                                Transmission System     modification.
                                Modeling and
                                Simulation.
MOD-013-1....................  RRO Dynamics Data       Pending.
                                Requirements and
                                Reporting Procedures.
MOD-014-0....................  Development of          Pending.
                                Interconnection-
                                Specific Steady State
                                System Models.
MOD-015-0....................  Development of          Pending.
                                Interconnection-
                                Specific Dynamics
                                System Models.
MOD-016-1....................  Actual and Forecast     Approve; direct
                                Demands, Net Energy     modification.
                                for Load,
                                Controllable DSM.
MOD-017-0....................  Aggregated Actual and   Approve; direct
                                Forecast Demands and    modification.
                                Net Energy for Load.
MOD-018-0....................  Reports of Actual and   Approve.
                                Forecast Demand Data.
MOD-019-0....................  Forecasts of            Approve; direct
                                Interruptible Demands   modification.
                                and DCLM Data.
MOD-020-0....................  Providing               Approve; direct
                                Interruptible Demands   modification.
                                and DCLM Data.
MOD-021-0....................  Accounting Methodology  Approve; direct
                                for Effects of          modification.
                                Controllable DSM in
                                Forecasts.
MOD-024-1....................  Verification of         Pending.
                                Generator Gross and
                                Net Real Power
                                Capability.
MOD-025-1....................  Verification of         Pending.
                                Generator Gross and
                                Net Reactive Power
                                Capability.
PER-001-0....................  Operating Personnel     Approve.
                                Responsibility and
                                Authority.
PER-002-1....................  Operating Personnel     Approve; direct
                                Training.               modification.
PER-003-0....................  Operating Personnel     Approve; direct
                                Credentials.            modification.
PER-004-0....................  Reliability             Approve; direct
                                Coordination--Staffin   modification.
                                g.
PRC-001-0....................  System Protection       Approve; direct
                                Coordination.           modification.
PRC-002-0....................  Define and Document     Pending.
                                Disturbance
                                Monitoring Equipment
                                Requirements.
PRC-003-1....................  Regional Requirements   Pending.
                                for Analysis of
                                Misoperations of
                                Transmission and
                                Generation Protection
                                Systems.
PRC-004-1....................  Analysis and            Approve.
                                Mitigation of
                                Transmission and
                                Generation Protection
                                System Misoperations.
PRC-005-1....................  Transmission and        Approve; direct
                                Generation Protection   modification.
                                System Maintenance
                                and Testing.
PRC-006-0....................  Development and         Pending.
                                Documentation of
                                Regional UFLS
                                Programs.
PRC-007-0....................  Assuring Consistency    Approve.
                                with Regional UFLS
                                Program.
PRC-008-0....................  Underfrequency Load     Approve; direct
                                Shedding Equipment      modification.
                                Maintenance Programs.
PRC-009-0....................  UFLS Performance        Approve.
                                Following an
                                Underfrequency Event.
PRC-010-0....................  Assessment of the       Approve; direct
                                Design and              modification.
                                Effectiveness of UVLS
                                Program.
PRC-011-0....................  UVLS System             Approve; direct
                                Maintenance and         modification.
                                Testing.
PRC-012-0....................  Special Protection      Pending.
                                System Review
                                Procedure.
PRC-013-0....................  Special Protection      Pending.
                                System Database.
PRC-014-0....................  Special Protection      Pending.
                                System Assessment.
PRC-015-0....................  Special Protection      Approve.
                                System Data and
                                Documentation.
PRC-016-0....................  Special Protection      Approve; direct
                                System Misoperations.   modification.
PRC-017-0....................  Special Protection      Approve; direct
                                System Maintenance      modification.
                                and Testing.
PRC-018-1....................  Disturbance Monitoring  Approve.
                                Equipment
                                Installation and Data
                                Reporting.
PRC-020-1....................  Under-Voltage Load      Pending.
                                Shedding Program
                                Database.
PRC-021-1....................  Under-Voltage Load      Approve.
                                Shedding Program Data.
PRC-022-1....................  Under-Voltage Load      Approve.
                                Shedding Program
                                Performance.
TOP-001-0....................  Reliability             Approve; direct
                                Responsibilities and    modification.
                                Authorities.
TOP-002-1....................  Normal Operations       Approve; direct
                                Planning.               modification.
TOP-003-0....................  Planned Outage          Approve; direct
                                Coordination.           modification.
TOP-004-0....................  Transmission            Approve; direct
                                Operations.             modification.
TOP-005-1....................  Operational             Approve; direct
                                Reliability             modification.
                                Information.
TOP-006-0....................  Monitoring System       Approve; direct
                                Conditions.             modification.
TOP-007-0....................  Reporting SOL and IROL  Approve.
                                Violations.
TOP-008-0....................  Response to             Approve; direct
                                Transmission Limit      modification.
                                Violations.
TPL-001-0....................  System Performance      Approve; direct
                                Under Normal            modification.
                                Conditions.
TPL-002-0....................  System Performance      Approve; direct
                                Following Loss of a     modification.
                                Single BES Element.

TPL-003-0....................  System Performance      Approve; direct
                                Following Loss of Two   modification.
                                or More BES Elements.
TPL-004-0....................  System Performance      Approve; direct
                                Following Extreme BES   modification.
                                Events.
TPL-005-0....................  Regional and            Pending.
                                Interregional Self-
                                Assessment
                                Reliability Reports.
TPL-006-0....................  Assessment Data from    Pending.
                                Regional Reliability
                                Organizations.
VAR-001-1....................  Voltage and Reactive    Approve; direct
                                Control.                modification.
VAR-002-1....................  Generator Operations    Approve
                                for Maintaining
                                Network Voltage
                                Schedules.
Glossary.....................  Glossary of Terms Used  Approve; direct
                                in Reliability          modification.
                                Standards.
Regional Difference..........  BAL-001: ERCOT: CPS2..  Approve.
Regional Difference..........  INT-001/4: WECC         Pending.
                                Tagging Dynamic
                                Schedules and
                                Inadvertent Payback.
Regional Difference..........  BAL-006: MISO RTO       Approve.
                                inadvertent
                                Interchange
                                Accounting.
Regional Difference..........  BAL-006: MISO/SPP       Approve.
                                Financial Inadvertent
                                Settlement.
Regional Difference..........  INT-003: MISO/SPP       Approve.
                                Scheduling Agent.
Regional Difference..........  INT-003: MISO Enhanced  Approve.
                                Scheduling Agent.
Regional Difference..........  INT-001/3: MISO Energy  Approve.
                                Flow Information.
Regional Difference..........  IRO-006: PJM/MISO/SPP   Pending.
                                Enhanced Congestion
                                Management.
------------------------------------------------------------------------

         Appendix B.--Commenters on Staff Preliminary Assessment
------------------------------------------------------------------------
           Abbreviation                           Commenter
------------------------------------------------------------------------
Alberta...........................  Alberta Department of Energy;
                                     Alberta Utilities and Energy Board;
                                     Alberta Electric System Operator.
Alcoa.............................  Alcoa, Inc. and Alcoa Power
                                     Generating Company.
Allegheny.........................  Allegheny Power and Allegheny Energy
                                     Supply Company, LLC.
Ameren Services Co................  Ameren.
American Transmission.............  American Transmission Company, LLC.
Professor Bose....................  Professor Anjan Bose.
APPA..............................  American Public Power Association.
BG&E..............................  Baltimore Gas & Electric Company.
BPA...............................  Bonneville Power Administration.
CPUC..............................  Public Utilities Commission of the
                                     State of California.
CEA...............................  Canadian Electricity Association.
Centerpoint.......................  CenterPoint Energy Houston Electric,
                                     LLC.
Redding...........................  City of Redding, California.
Duke..............................  Duke Energy Corporation.
E.ON U.S..........................  E.ON U.S. LLC.
EEI...............................  Edison Electric Institute.
FPL Energy........................  FPL Energy.
FRCC..............................  Florida Reliability Coordinating
                                     Council.
Georgia System....................  Georgia System Operations
                                     Corporation.
Hydro One.........................  Hydro One Networks Inc.
ISO/RTO Council...................  The ISO/RTO Council.
KeySpan...........................  KeySpan--Ravenswood, LLC.
LPPC..............................  Large Public Power Council.
MEAG..............................  MEAG Power.
MidAmerican.......................  MidAmerican Energy Company.
MISO..............................  Midwest Independent Transmission
                                     System Operator, Inc.
MRO...............................  Midwest Reliability Organization.
Multiple Intervenors..............  Multiple Intervenors, an
                                     unincorporated association of
                                     approximately 55 large industrial,
                                     commercial and institutional end-
                                     use energy consumers with
                                     facilities in New York.
National Grid.....................  National Grid USA.
NCPA..............................  Northern California Power Agency.
NEMA..............................  National Electrical Manufacturers
                                     Association.
NERC..............................  North American Electric Reliability
                                     Council.
New York Commission...............  New York State Public Service
                                     Commission.
NPCC..............................  Northeast Power Coordinating
                                     Council.
NRECA.............................  National Rural Electric Cooperative
                                     Association.
NYSRC.............................  New York State Reliability Council
                                     LLC.
Ohio Consumers' Council...........  Ohio Consumers' Council.
Old Dominion......................  Old Dominion Electric Cooperative.
Ontario IESO......................  Ontario Independent Electricity
                                     System Operator.
PG&E..............................  Pacific Gas & Electric Company.
PSEG Companies....................  Public Service Electric & Gas
                                     Company, PSEG Energy Resources &
                                     Trade LLC, PSEG Power LLC.
ReliabilityFirst..................  ReliabilityFirst Corporation.
SDG&E.............................  San Diego Gas & Electric Company.
SoCal Edison......................  Southern California Edison Company.
Southern..........................  Southern Company Services, Inc.

Southwest TDU.....................  Southwest Transmission Dependent
                                     Utility Group.
TANC..............................  Transmission Agency of Northern
                                     California.
TAPS..............................  Transmission Access Policy Study
                                     Group.
TVA...............................  Tennessee Valley Authority.
USDA Forest Service...............  U.S. Department of Agriculture
                                     Forest Service.
Valley Group......................  The Valley Group, Inc.
WECC..............................  Western Electricity Coordinating
                                     Council.
WECC OIWG.........................  Operating Issues Work Group, a work
                                     group of WECC's Compliance
                                     Monitoring and Operating Practices
                                     Subcommittee.
WECC/OTS..........................  Operations and Training
                                     Subcommittee, a subcommittee of
                                     WECC's Operating Committee.
Wisconsin Electric................  Wisconsin Electric Power Company.
------------------------------------------------------------------------

               Appendix C.--Abbreviations in This Document
------------------------------------------------------------------------

------------------------------------------------------------------------
ACE...............................  Area Control Error.
AGC...............................  Automatic Generation Control.
ANSI..............................  American National Standards
                                     Institute.
ATC...............................  Available Transfer Capability.
BCP...............................  Blackstart Capability Plan.
CBM...............................  Capacity Benefit Margin.
CPS...............................  Control Performance Standard.
DC................................  Direct Current.
DCS...............................  Disturbance Control Standard.
ERO...............................  Electric Reliability Organization.
GWh...............................  Gigawatt Hour.
IEEE..............................  Institute of Electrical and
                                     Electronics Engineers.
IROL..............................  Interconnection Reliability
                                     Operating Limits.
MW................................  Mega Watt.
ROW...............................  Right of Way.
SOL...............................  System Operating Limit.
SPS...............................  Special Protection System.
TIS...............................  Transmission Issues Subcommittee.
TLR...............................  Transmission Loading Relief.
TRM...............................  Transmission Reliability Margin.
TTC...............................  Total Transfer Capability.
UFLS..............................  Under Frequency Load Shedding.
UVLS..............................  Under Voltage Load Shedding.
------------------------------------------------------------------------

                     Appendix D.--High Priority List
------------------------------------------------------------------------
       Reliability standard                         Title
------------------------------------------------------------------------
COM-001-0.........................  Telecommunications.
COM-002-1.........................  Communications and Coordination.
EOP-002-0.........................  Capacity and Energy Emergency.
EOP-003-0.........................  Load Shedding Plans.
EOP-008-0.........................  Plans for Loss of Control Center
                                     Functionality.
FAC-003-1.........................  Vegetation Management Program.
FAC-008-1.........................  Facility Ratings Methodology.
IRO-003-1.........................  Reliability Coordination--Wide Area
                                     View.
IRO-006-3.........................  Reliability Coordination--
                                     Transmission Loading Relief.
PER-002-0.........................  Operating Personnel Training.
PER-003-0.........................  Operating Personnel Credentials.
PER-004-0.........................  Reliability Coordination--Staffing.
PRC-006-0.........................  Development and Documentation of
                                     Regional UFLS Programs.
PRC-020-1.........................  Under-Voltage Load Shedding Program
                                     Database.
TOP-006-0.........................  Monitoring System Conditions.
VAR-001-1.........................  Voltage and Reactive Control.
------------------------------------------------------------------------

[FR Doc. 06-8927 Filed 11-2-06; 8:45 am]

BILLING CODE 6717-01-P


[Federal Register Volume 74, Number 115 (Wednesday, June 17, 2009)]
[Notices]
[Page 28734]
[FR Doc No: E9-14175]

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SECURITIES AND EXCHANGE COMMISSION

Proposed Collection; Comment Request

Upon Written Request, Copies Available From: Securities and Exchange
Commission, Office of Investor Education and Advocacy, Washington, DC
20549-0213.

Extension:
    Form F-80; OMB Control No. 3235-0404; SEC File No. 270-357.

    Notice is hereby given that, pursuant to the Paperwork Reduction
Act of 1995 (44 U.S.C. 3501 et seq.), the Securities and Exchange
Commission (``Commission'') is soliciting comments on the collection of
information summarized below. The Commission plans to submit this
existing collection of information to the Office of Management Budget
for extension and approval.
    Form F-80 (17 CFR 239.41) is used by large, publicly-traded
Canadian foreign private issuers registering securities that are
offered in business combinations and exchange offers. The information
collected is intended to ensure that the information required to be
filed by the Commission permits verification of compliance with
securities law requirements and assures the public availability of the
information. Form F-80 takes approximately 2 hours per response and is
filed by 4 issuers for a total annual burden of 8 hours. The estimated
burden of 2 hours per response was based upon the amount of time
necessary to compile the registration statement using the existing
Canadian prospectus plus any additional information required by the
Commission.
    Written comments are invited on: (a) Whether this proposed
collection of information is necessary for the proper performance of
the functions of the agency, including whether the information will
have practical utility; (b) the accuracy of the agency's estimate of
the burden imposed by the collection of information; (c) ways to
enhance the quality, utility, and clarity of the information collected;
and (d) ways to minimize the burden of the collections of information
on respondents, including through the use of automated collection
techniques or other forms of information technology. Consideration will
be given to comments and suggestions submitted in writing within 60
days of this publication.
    Please direct your written comments to Charles Boucher/CIO,
Securities and Exchange Commission, C/O Shirley Martinson, 6432 General
Green Way, Alexandria, Virginia 22312; or send an e-mail to<EMAIL_ADDRESS>
    Dated: June 10, 2009.
Florence E. Harmon,
Deputy Secretary.
[FR Doc. E9-14175 Filed 6-16-09; 8:45 am]
BILLING CODE 8010-01-P