Order approving EOP-008-1 Reliability Standard

Federal Register / Vol. 76, No. 82 / Thursday, April 28, 2011 / Notices
accordance with the Commission’s
Rules may become a party to the
proceeding. Any comments, protests, or
motions to intervene must be received
on or before the specified comment date
for the particular application.
All filings must (1) bear in all capital
letters the title ‘‘PROTEST’’, ‘‘MOTION
TO INTERVENE’’, ‘‘COMMENTS,’’
‘‘REPLY COMMENTS,’’
‘‘RECOMMENDATIONS,’’
‘‘PRELIMINARY TERMS AND
CONDITIONS,’’ or ‘‘PRELIMINARY
FISHWAY PRESCRIPTIONS;’’ (2) set
forth in the heading the name of the
applicant and the project number of the
application to which the filing
responds; (3) furnish the name, address,
and telephone number of the person
protesting or intervening; and (4)
otherwise comply with the requirements
of 18 CFR 385.2001 through 385.2005.
All comments, recommendations, terms
and conditions or prescriptions must set
forth their evidentiary basis and
otherwise comply with the requirements
of 18 CFR 4.34(b). Agencies may obtain
copies of the application directly from
the applicant. A copy of any protest or
motion to intervene must be served
upon each representative of the
applicant specified in the particular
application. A copy of all other filings
in reference to this application must be
accompanied by proof of service on all
persons listed in the service list
prepared by the Commission in this
proceeding, in accordance with 18 CFR
4.34(b) and 385.2010.
p. Procedural Schedule:
The application will be processed
according to the following revised
Hydro Licensing Schedule. Revisions to
the schedule may be made as
appropriate.
Milestone
Filing of recommendations,
preliminary terms and
conditions, and preliminary fishway prescriptions.
Commission issues EA .......
Comments on EA ................

srobinson on DSKHWCL6B1PROD with NOTICES

Modified terms and conditions.

Target Date
June 2011.

October 2011.
November
2011.
January 2012.

q. Final amendments to the
application must be filed with the
Commission no later than 30 days from
the issuance date of this notice.
r. A license applicant must file no
later than 60 days following the date of
issuance of the notice of acceptance and
ready for environmental analysis
provided for in 5.22: (1) A copy of the
water quality certification; (2) a copy of
the request for certification, including
proof of the date on which the certifying

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agency received the request; or (3)
evidence of waiver of water quality
certification.
Dated: April 21, 2011.
Kimberly D. Bose,
Secretary.
[FR Doc. 2011–10260 Filed 4–27–11; 8:45 am]
BILLING CODE 6717–01–P

DEPARTMENT OF ENERGY
Federal Energy Regulatory
Commission
[Docket No. RD11–4–000]

North American Electric Reliability
Corporation; Order Approving
Reliability Standard
April 21, 2011.
Before Commissioners: Jon Wellinghoff,
Chairman; Marc Spitzer, Philip D. Moeller,
John R. Norris, and Cheryl A. LaFleur.

1. On February 11, 2011, the North
American Electric Reliability
Corporation (NERC), the Commissioncertified Electric Reliability
Organization (ERO), submitted a
petition for Commission approval of
Emergency Preparedness and
Operations (EOP) Reliability Standard
EOP–008–1 (Loss of Control Center
Functionality). The Reliability Standard
requires reliability coordinators,
transmission operators, and balancing
authorities to have an operating plan
and facilities for backup functionality to
ensure Bulk-Power System reliability in
the event that a control center becomes
inoperable. NERC also requests that the
Commission approve the retirement of
currently effective EOP–008–0
concurrent with the effectiveness of the
Standard approved in this Order.
2. In this order, we approve
Reliability Standard EOP–008–1,
finding that the Reliability Standard is
just, reasonable, not unduly
discriminatory or preferential, and in
the public interest. In addition, we
approve the retirement of EOP–008–0 as
requested by NERC. Also, we approve
NERC’s requested effective date, i.e., the
date in which applicable entities are
subject to mandatory compliance, of 24
months after the first day of the first
quarter after approval.
I. Background
3. Currently-effective Reliability
Standard EOP–008–0 (Plans for Loss of
Control Center Functionality) contains a
single Requirement R1, which provides
‘‘Each Reliability Coordinator,
Transmission Operator and Balancing
Authority shall have a plan to continue
reliability operations in the event its

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control center becomes inoperable.’’
Requirement R1 also identifies
mandatory elements of the continuity
plan.
4. On March 16, 2007, the
Commission issued Order No. 693
approving 83 Reliability Standards
proposed by NERC, including EOP
Reliability Standard EOP–008–0.1 In
addition, pursuant to section 215(d)(5)
of the FPA, the Commission directed the
ERO to develop modifications to EOP–
008–0 to address specific issues
identified by the Commission. In
particular, the Commission directed the
ERO to develop a modification through
the Reliability Standards development
process that includes a Requirement
that provides, as a minimum, for backup
capabilities that are independent from
the primary control center, capable to
operate for a prolonged period
corresponding to the time it would take
to replace the primary control center,
and provide a minimum set of tools and
facilities to replicate the critical
reliability functions of the primary
control center.2 The Commission
directed that the extent of the backup
capability should be consistent with the
impact of the loss of the entity’s primary
control center on the reliability of the
Bulk-Power System.
5. The Commission also directed that
reliability coordinators have fully
complete, dedicated backup control
centers.3 In addition, the Commission
directed the ERO to modify the
Reliability Standard to require that
transmission operators and balancing
authorities having operational control
over significant portions of generation
and load have minimum backup
capabilities that replicate the critical
reliability functions of the primary
control center, but they may do so
through contracting for these services
instead of through dedicated backup
control centers.4
II. NERC Petition
A. NERC Description of the Benefits of
Reliability Standard EOP–008–1
6. In its February 11, 2011 filing,5
NERC requests Commission approval of
1 Mandatory Reliability Standards for the BulkPower System, Order No. 693, FERC Stats. & Regs.
¶ 31,242, order on reh’g, Order No. 693–A, 120
FERC ¶ 61,053 (2007).
2 Id. P 663, 672.
3 Id. P 670
4 Id. P 670, 672.
5 North American Electric Reliability Corp.,
February 11, 2011 Petition of the North American
Electric Reliability Corporation for Approval of One
Emergency Preparedness and Operations Reliability
Standard EOP–008–1 and Retirement of One
Existing Reliability Standard EOP–008–0 (NERC
Petition).

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proposed Reliability Standard EOP–
008–1. NERC states that EOP–008–1 is
intended to ensure that a plan is in
place for backup functionality and that
facilities and personnel are prepared to
implement that plan. NERC states that
the proposed Reliability Standard
represents a significant revision and
improvement to the current Standard by
eliminating gaps, reducing ambiguity,
eliminating fill-in-the-blank
components, and addressing the
relevant Commission directives in Order
No. 693.
7. Discussing the benefits of EOP–
008–1, NERC states that the Reliability
Standard: (1) Delineates what must be
included in a plan for backup
functionality; (2) includes a provision
for managing the risk to the Bulk-Power
System during the transition from
primary to backup functionality; (3)
requires reliability coordinators to have
a dedicated facility for its backup
functionality; (4) provides that
transmission operators and balancing
authorities can have either a dedicated
facility or may contract for services to
provide backup functionality; (5)
address the need for formal review and
approval of the plan for backup
functionality; (6) mandates
independence of the primary and
backup capabilities; (7) requires testing
of the plan; and (8) establishes a
procedure for creating a plan to reestablish backup capability following a
catastrophic situation.6 In addition,
NERC discusses how EOP–008–1
satisfies the factors set forth in Order
No. 672 for analyzing whether a
Reliability Standard is just, reasonable,
not unduly discriminatory or
preferential, and in the public interest.7

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B. Reliability Standard EOP–008–1
8. Reliability Standard EOP–008–1
contains eight Requirements for the
stated purpose of ensuring continued
reliable operations of the bulk electric
system in the event that a control center
becomes inoperable. Requirement R1
requires each applicable entity to have
a current operating plan describing the
manner in which it will continue to
meet its functional obligations in the
event that its primary control center
functionality is lost. Requirement R2
6 NERC Petition at 4. Pursuant to 18 CFR 40.3
(2010), the ERO must post on its Web site currently
effective Reliability Standards. NERC has posted
Reliability Standard EOP–008–1 on the NERC Web
site at http://www.nerc.com/page.php?cid=2|20.
7 NERC Petition at 8–18. Rules Concerning
Certification of the Electric Reliability Organization;
and Procedures for the Establishment, Approval
and Enforcement of Electric Reliability Standards,
Order No. 672, FERC Stats. & Regs. ¶ 31,204, order
on reh’g, Order No. 672–A, FERC Stats. & Regs.
¶ 31,212 (2006).

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instructs each applicable entity to have
a copy of its current plan for backup
functionality at its primary control
center and at the location providing
backup functionality. Requirement R3
mandates that each reliability
coordinator have a backup control
center that provides functionality
sufficient to maintain compliance with
all Reliability Standards that depend on
primary control center functionality.
9. Reliability Standard EOP–008–1,
Requirement R4 directs balancing
authorities and transmission operators
to have a backup functionality, either
through a facility or contracted services,
to maintain compliance with all
Reliability Standards that depend on
their primary control center
functionality. Requirement R5 requires
each applicable entity to review
annually and approve its plan for
backup functionality, and Requirement
R7 requires each applicable entity to
annually test and document the results
of its plan demonstrating the transition
time between the simulated loss of the
primary control center and the full
implementation of the backup
functionality. Requirement R6 mandates
that primary and backup functionality
cannot depend on each other. Finally,
each reliability coordinator, balancing
authority or transmission operator that
experiences a loss of either primary or
backup functionality anticipated to last
for more than six months must, in
accordance with Requirement R8,
provide a plan to its Regional Entity
within six calendar months of the date
when functionality is lost showing how
it will re-establish such functionality.
III. Notice of Filing, Interventions and
Comments
10. On February 16, 2011, notice of
NERC’s filing was published in the
Federal Register with interventions and
protests due on or before March 4,
2011.8 Motions to intervene were timely
filed by American Municipal Power,
Inc. (AMP) and Modesto Irrigation
District (MID). The ISO/RTO Council
(ISO/RTO) timely filed a motion to
intervene and comments supporting the
adoption of proposed Reliability
Standard EOP–008–1 and the
concurrent retirement of EOP–008–0.
Pursuant to Rule 214 of the
Commission’s Rules of Practice and
Procedure,9 the timely, unopposed
motions to intervene serve to make
AMP, MID, and ISO/RTO parties to this
proceeding.

IV. Discussion
11. The Commission approves
Reliability Standard EOP–008–1 as just,
reasonable, not unduly discriminatory
or preferential and in the public
interest.10 By providing detailed
requirements for what must be included
in a plan to meet functional obligations
in the event a primary control center is
lost, by now requiring formal, annual
approval of such plans, and by
specifically requiring reliability
coordinators to have backup facilities
and transmission operators and
balancing authorities to have backup
functionality, EOP–008–1 represents a
significant improvement to the currently
effective Reliability Standard. The
revised Standard addresses the relevant
directives in Order No. 693 and
specifically requires, among other
things, independent backup capabilities,
capable of operating for a prolonged
period, and providing functionality
sufficient to maintain compliance with
all Reliability Standards that depend on
primary control functionality.
12. Reliability Standard EOP–008–1
requires that all applicable entities have
backup functionality. Reliability
coordinators in particular must have full
backup control centers while balancing
authorities and transmission operators
may elect to attain backup functionality
either by a dedicated facility or by
contracted service. This distinction
recognizes the comparative difference in
the scope of responsibility for a
reliability coordinator versus a
balancing authority or transmission
operator, and the Standard satisfies the
Commission directives in this regard.11
13. Additionally, we note that
Requirement R1 (section 1.5) permits a
transition time between the loss of the
primary control center and full
implementation of backup functionality
of up to two hours. NERC states that, in
the standards development process,
some stakeholders commented that the
two hour transition period was too long,
others considered it too short, and some
argued that the timeframe seemed to
weaken the current requirement.12
According to NERC, the standards
drafting team ‘‘attempted to develop a
reasonable number that would allow for
a backup control center to be placed
sufficiently far away so that the chances
of a single catastrophe affecting both
sites were minimal, versus having it so
far away that there may be a serious gap
10 16

U.S.C. 824(d)(2).
Order No. 693, FERC Stats. & Regs.
¶ 31,242 at P 670.
12 NERC Petition at 37–38.
11 See

8 76
9 18

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Federal Register / Vol. 76, No. 82 / Thursday, April 28, 2011 / Notices
in reliability during the intervening time
before the backup is operational.’’ 13
14. The Commission is concerned that
the two hour transition period may
expose the grid to increased reliability
risk without control functionality. For
this reason it is imperative that full
backup functionality occur as soon as
possible after the loss of primary control
functionality. Nonetheless, until data
from drills, exercises and tests can
support a specific time period, the
Commission approves the Reliability
Standard but notes it may revisit this
transition timeframe once the applicable
entities have developed experience
operating under this new Standard.
15. Accordingly, the Commission
approves Reliability Standard EOP–
008–1, effective the first day of the first
calendar quarter twenty-four months
after Commission approval. Further, as
requested by NERC, we approve the
retirement of currently-effective
Reliability Standard EOP–008–0
concurrent with the implementation
date of EOP–008–1.

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V. Violation Risk Factors/Violation
Security Levels
16. To determine a base penalty
amount for a violation of a Requirement
within a Reliability Standard, NERC
must first determine an initial range for
the base penalty amount. To do so,
NERC assigns a violation risk factor to
each Requirement and sub-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.
The Commission has established
guidelines for evaluating the validity of
each violation risk factor assignment.14
17. NERC also will assign each
Requirement and sub-Requirement one
of four violation severity levels—low,
moderate, high, and severe—as
measurements for the degree to which
the Requirement was violated in a
specific circumstance. On June 19, 2008,
the Commission issued an order
establishing four guidelines for the
development of violation severity
levels.15
18. With respect to Reliability
Standard EOP–008–1, NERC has
assigned violation risk factors only to
the main Requirements and did not
propose violation risk factors for any of
13 Id.
14 See North American Electric Reliability Corp.,
119 FERC ¶ 61,145, order on reh’g, 120 FERC
¶ 61,145, at P 8–13 (2007).
15 North American Electric Reliability Corp., 123
FERC ¶ 61,284, at P 20–35, order on reh’g &
compliance, 125 FERC ¶ 61,212 (2008).

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the sub-Requirements.16 NERC noted
that such practice is consistent with
NERC’s August 10, 2009 informational
filing regarding the assignment of
violation risk factors and violation
severity levels.17
19. On May 5, 2010, NERC
incorporated by reference into Docket
No. RR08–4–005,18 its August 10, 2009
Information Filing in which NERC
proposes assigning violation risk factors
and violation severity levels only to the
main Requirements in each Reliability
Standard, and not to the subRequirements. Because the assignment
of violation risk factors and violation
severity levels for EOP–008–1 is made
in accordance with NERC’s pending
petition, the Commission defers
discussion of the proposed violation
risk factors and violation severity levels
until after the Commission issues a final
order acting on NERC’s petition in
Docket No. RR08–4–005.
VI. Information Collection Statement
20. The Office of Management and
Budget (OMB) regulations require
approval of certain information
collection requirements imposed by
agency action.19 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 Order
will not be penalized for failing to
respond to these collections of
information unless the collections of
information display a valid OMB
control number.
21. The Commission is submitting
these reporting and recordkeeping
requirements to OMB for its review and
approval under section 3507(d) of the
Paperwork Reduction Act. 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
16 We note that in Version Two Facilities Design,
Connections and Maintenance Reliability
Standards, Order No. 722, 126 FERC ¶ 61,255, at P
45 (2009), the ERO proposed to develop violation
risk factors and violation severity levels for
Requirements but not sub-requirements. The
Commission denied the proposal as ‘‘premature’’
and, instead, encouraged the ERO to ‘‘develop a new
and comprehensive approach that would better
facilitate the assignment of violation severity levels
and violation risk factors.’’ As directed, on March
5, 2010, NERC submitted a comprehensive
approach that is currently pending with the
Commission in Docket No. RR08–4–005.
17 NERC Petition at 16–17.
18 Docket No. RR08–4–005 comprises NERC’s
March 5, 2010 Violation Severity Level Compliance
Filing submitted in response to Order No. 722. See
Order No. 722, 126 FERC ¶ 61,255 at P 45.
19 5 CFR 1320.11.

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23803

be collected, and any suggested methods
for minimizing the respondent’s burden,
including the use of automated
information techniques.
22. Rather than creating entirely new
obligations with respect to the loss of
control center functionality, Reliability
Standard EOP–008–1 upgrades the
existing planning requirements
contained in EOP–008–0 and
specifically requires reliability
coordinators, balancing authorities and
transmission operators to have backup
functionality. Thus, this Order does not
impose entirely new burdens on the
effected entities. For example, EOP–
008–0 requires each applicable entity to
have a plan to continue reliable
operations in the event its control center
becomes inoperable and to conduct
reviews and tests, at least annually, to
ensure viability of the plan. This Order,
however, imposes new requirements
regarding the approval, placement,
documentation and updating of plans as
well as requires entities that may not
already possessing backup functionality
to obtain, possibly through contractual
arrangements, backup capabilities.
23. Burden Estimate: Our estimate
below regarding the number of
respondents is based on the NERC
compliance registry as of February 17,
2011. According to the registry, there
are 23 reliability coordinators, 120
balancing authorities and 176
transmission operators that will be
involved in providing information.
Under NERC’s compliance registration
program, however, entities may be
registered for multiple functions or,
particularly in the case of reliability
coordinators, registered for the same
function with multiple regional entities,
so these numbers incorporate some
double counting. The net number of
entities responding will be 215,
consisting of 17 reliability coordinators,
94 entities registered as both balancing
authorities and transmission operators,
and 104 entities registered solely as
either a balancing authority or a
transmission operator. This Order will
require applicable entities to revise their
plans and document compliance with
the Reliability Standard’s requirements.
For those balancing authorities and
transmission operators that do not
already comply with the Standard’s
requirement for backup functionality,
they will, at a minimum, be required to
contract for such services. We
understand that all reliability
coordinators currently have backup
control centers and estimate that
approximately 27 entities will have to
procure backup functionality. The
estimated burden for the requirements
in this Order follow:

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FERC–725A
Data collection

Number of
respondents

Number of
annual
responses per
respondent

Hours per
respondent per
response

Total annual
hours

(A)

(B)

(C)

(A × B × C)

Review and possible revision of plan (one-time) .............................
Updating, approving, and maintaining records .................................

215
215

1
1

Balancing authorities and transmission operators contracting for
backup functionality (one-time).
Total one-time ...................................................................................
Total recurring ...................................................................................

27

Total ...........................................................................................

Information Collection Costs: The
Commission seeks comments on the
costs to comply with these requirements
and recordkeeping burden associated
with Reliability Standard EOP–008–1.
• Total Annual Hours for Collection:
(Compliance/Documentation +
Contracting) = 9,260 hours.
• Total One-Time Compliance Cost =
7,540 hours @ $120/hour = $904,800.
• Total Reoccurring Compliance
Cost = 1,720 hours @ $120/hour =
$206,400.
• Total Recordkeeping Cost = 430
hours @ $28/hour = $10,240
• Total First Year Cost = $1,121,440.
• Title: Mandatory Reliability
Standards for the Bulk-Power System.
• Action: FERC 725A, Proposed
Modification to FERC–725A.
• OMB Control No: 1902–0244.
• Respondents: Business or other for
profit, and/or not for profit institutions.
• Frequency of Responses: On
occasion.
• Necessity of the Information: This
Order approves revised Reliability
Standard that modifies an existing
requirement regarding preparing for the
loss of control center functionality.
Reliability Standard EOP–008–1
requires entities to revise and authorize
operating plans for backup control
center functionality. It also requires
some entities to procure such backup
functionality, and in every case imposes
requirements to retain records.
24. 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, e-mail:
DataClearance@ferc.gov, Phone: (202)
502–8663, fax: (202) 273–0873].
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

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1

20 .....................
Compliance: 6 ..
Recordkeeping:
2.
120 ...................

3,240

............................
............................

............................
............................

...........................
...........................

7,540
1,720

............................

............................

...........................

9,260

Officer for the Federal Energy
Regulatory Commission]. For security
reasons, comments should be sent by email to OMB at oira_submission@
omb.eop.gov. Please reference OMB
Control Number 1902–0244 and the
docket number of this Order in your
submission.
VII. Environmental Analysis
25. The Commission is required to
prepare an Environmental Assessment
or an Environmental Impact Statement
for any action that may have a
significant adverse effect on the human
environment.20 The action taken in the
Order falls within the categorical
exclusion in the Commission’s
regulations for orders that are clarifying,
corrective or procedural, for information
gathering, analysis, and
dissemination.21 Accordingly, neither
an environmental impact statement nor
an environmental assessment is
required.
VIII. Regulatory Flexibility Act
26. The Regulatory Flexibility Act of
1980 (RFA) 22 generally requires a
description and analysis of orders that
will have significant economic impact
on a substantial number of small
entities. The RFA mandates
consideration of regulatory alternatives
that accomplish the stated objectives of
a proposed order and that minimize any
significant economic impact on a
substantial number of small entities.
The Small Business Administration’s
(SBA’s) Office of Size Standards
develops the numerical definition of a
small business.23 The SBA has
established a size standard for electric
utilities, stating that a firm is small if,
20 Regulations Implementing the National
Environmental Policy Act, Order No. 486, 52 FR
47897 (Dec. 17, 1987), FERC Stats. & Regs.,
Regulations Preambles 1986–1990 ¶ 30,783 (1987).
21 18 CFR 380.4(a)(5).
22 5 U.S.C. 601–12.
23 13 CFR 121.101.

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4,300
1,290
430

including its affiliates, it is primarily
engaged in the transmission, generation
and/or distribution of electric energy for
sale and its total electric output for the
preceding twelve months did not exceed
four million megawatt-hours.24
27. Comparison of the NERC
compliance registry with data submitted
to the Energy Information
Administration on Form EIA–861
indicates that perhaps as many as 54
balancing authorities and transmission
operators to which the requirements of
this Reliability Standard will apply will
be deemed small entities. Reliability
Standard EOP–008–1 clarifies the
elements of a plan for the loss of control
center functionality, imposes approval
and updating requirements for such
plans, and requires balancing
authorities and transmission operators
to have backup control center
functionality. Of the 54 small entities,
each will incur the compliance and
recordkeeping costs of $3,176 associated
with revising, approving, maintaining
and updating their plans for loss of
control center operability, but only that
subset of small entities that has not
already obtained backup control center
functionality, which we estimate to be
27 entities, will face the one-time
additional $14,400 burden of
contracting for such functionality. The
Commission estimates that, in addition
to the cost of contracting, the first year’s
cost of obtaining backup functionality
will be approximately $210,000 with
each subsequent year costing $60,000.
In aggregate, the Commission estimates
that this Reliability Standard may
impose on small entities that do not
currently have backup functionality an
initial cost of perhaps $227,576 with the
cost of subsequent years being reduced
to $60,776. Accordingly, the cost of
Reliability Standard EOP–008–1 should
not present a significant operating cost
to a substantial number of small entities.
24 13

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Federal Register / Vol. 76, No. 82 / Thursday, April 28, 2011 / Notices
28. Based on this understanding, the
Commission certifies that this
Reliability Standard will not have a
significant economic impact on a
substantial number of small entities.
Accordingly, no regulatory flexibility
analysis is required.
IX. Effective Date
29. This order will become effective
June 27, 2011.
The Commission Orders
(A) Reliability Standard EOP–008–1,
submitted by the North American
Electric Reliability Corporation, is
hereby approved, as discussed in the
body of this order.
(B) Reliability Standard EOP–008–0 is
hereby retired upon implementation of
EOP–008–1, as discussed in the body of
this order.
By the Commission.
Nathaniel J. Davis, Sr.,
Deputy Secretary.
[FR Doc. 2011–10266 Filed 4–27–11; 8:45 am]
BILLING CODE 6717–01–P

DEPARTMENT OF ENERGY
Federal Energy Regulatory
Commission

srobinson on DSKHWCL6B1PROD with NOTICES

Combined Notice of Filings #1
Take notice that the Commission
received the following electric corporate
filings:
Docket Numbers: EC11–73–000.
Applicants: Standard Binghamton
LLC, Alliance Energy, New York LLC,
Standard Power LLC.
Description: Application of Standard
Binghamton LLC, et al.
Filed Date: 04/22/2011.
Accession Number: 20110422–5044.
Comment Date: 5 p.m. Eastern Time
on Friday, May 13, 2011.
Take notice that the Commission
received the following electric rate
filings:
Docket Numbers: ER11–3048–000.
Applicants: ISO New England Inc.
Description: ISO New England Inc.’s
additional information regarding the
Installed Capacity Requirement Values
for the 2014/2015 Capability Year
Forward Capacity Auction, pursuant to
the FERC Deficiency Letter dated April
14.
Filed Date: 04/20/2011.
Accession Number: 20110420–5186.
Comment Date: 5 p.m. Eastern Time
on Friday, April 29, 2011.
Docket Numbers: ER11–3048–000.
Applicants: ISO New England Inc.
Description: ISO New England Inc.’s
Motion for Leave to File One Day Out-

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of-Time Supporting Materials, Including
CEII, in Response to Deficiency Letter.
Filed Date: 04/21/2011.
Accession Number: 20110421–5167.
Comment Date: 5 p.m. Eastern Time
on Friday, April 29, 2011.
Docket Numbers: ER11–3414–000.
Applicants: Blue Canyon Windpower
VI LLC.
Description: Blue Canyon Windpower
VI LLC submits tariff filing per 35.12:
Blue Canyon Windpower VI LLC MBR
Tariff to be effective 6/20/2011.
Filed Date: 04/21/2011.
Accession Number: 20110421–5142.
Comment Date: 5 p.m. Eastern Time
on Thursday, May 12, 2011.
Docket Numbers: ER11–3415–000.
Applicants: Midwest Independent
Transmission System Operator, Inc.
Description: Midwest Independent
Transmission System Operator, Inc.
submits tariff filing per 35.13(a)(2)(iii):
04–21–11 Exit Fee Agmt to be effective
5/31/2011.
Filed Date: 04/21/2011.
Accession Number: 20110421–5143.
Comment Date: 5 p.m. Eastern Time
on Thursday, May 12, 2011.
Docket Numbers: ER11–3416–000.
Applicants: Alta Wind VI, LLC.
Description: Alta Wind VI, LLC
submits tariff filing per 35.12: Alta
Wind VI, LLC MBR Tariff to be effective
5/16/2011.
Filed Date: 04/21/2011.
Accession Number: 20110421–5147.
Comment Date: 5 p.m. Eastern Time
on Thursday, May 12, 2011.
Docket Numbers: ER11–3417–000.
Applicants: Alta Wind VIII, LLC.
Description: Alta Wind VIII, LLC
submits tariff filing per 35.12: Alta
Wind VIII, LLC MBR Tariff to be
effective 5/16/2011.
Filed Date: 04/21/2011.
Accession Number: 20110421–5148.
Comment Date: 5 p.m. Eastern Time
on Thursday, May 12, 2011.
Docket Numbers: ER11–3418–000.
Applicants: Xoom Energy, LLC.
Description: Xoom Energy, LLC
submits tariff filing per 35.12: Xoom
Energy, LLC Application for MarketBased Rates to be effective 5/23/2011.
Filed Date: 04/21/2011.
Accession Number: 20110421–5155.
Comment Date: 5 p.m. Eastern Time
on Thursday, May 12, 2011.
Docket Numbers: ER11–3419–000.
Applicants: South Carolina Electric &
Gas Company.
Description: South Carolina Electric &
Gas Company submits tariff filing per
35.13(a)(2)(iii): FERC Electric Rate
Schedule No. 60 to be effective 4/21/
2011.

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Filed Date: 04/21/2011.
Accession Number: 20110421–5189.
Comment Date: 5 p.m. Eastern Time
on Thursday, May 12, 2011.
Take notice that the Commission
received the following electric securities
filings:
Docket Numbers: ES11–22–000.
Applicants: Midwest Independent
Transmission System Operator, Inc.
Description: Second Amendment to
Application of the Midwest
Independent Transmission System
Operator, Inc. under Section 204 of the
Federal Power Act to Issue Securities.
Filed Date: 04/21/2011.
Accession Number: 20110421–5191.
Comment Date: 5 p.m. Eastern Time
on Monday, May 2, 2011.
Any person desiring to intervene or to
protest in any of the above proceedings
must file in accordance with Rules 211
and 214 of the Commission’s Rules of
Practice and Procedure (18 CFR 385.211
and 385.214) on or before 5 p.m. Eastern
time on the specified comment date. It
is not necessary to separately intervene
again in a subdocket related to a
compliance filing if you have previously
intervened in the same docket. Protests
will be considered by the Commission
in determining the appropriate action to
be taken, but will not serve to make
protestants parties to the proceeding.
Anyone filing a motion to intervene or
protest must serve a copy of that
document on the Applicant. In reference
to filings initiating a new proceeding,
interventions or protests submitted on
or before the comment deadline need
not be served on persons other than the
Applicant.
As it relates to any qualifying facility
filings, the notices of self-certification
[or self-recertification] listed above, do
not institute a proceeding regarding
qualifying facility status. A notice of
self-certification [or self-recertification]
simply provides notification that the
entity making the filing has determined
the facility named in the notice meets
the applicable criteria to be a qualifying
facility. Intervention and/or protest do
not lie in dockets that are qualifying
facility self-certifications or selfrecertifications. Any person seeking to
challenge such qualifying facility status
may do so by filing a motion pursuant
to 18 CFR 292.207(d)(iii). Intervention
and protests may be filed in response to
notices of qualifying facility dockets
other than self-certifications and selfrecertifications.
The Commission encourages
electronic submission of protests and
interventions in lieu of paper, using the
FERC Online links at http://
www.ferc.gov. To facilitate electronic

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