Federal Register: December 27, 2010 (Volume 75, Number 247)
DOCID: fr27de10-19 FR Doc 2010-32356
DEPARTMENT OF ENERGY
Federal Energy Regulatory Commission
CFR Citation: 18 CFR Part 40
Docket ID: [Docket No. RM10-5-000]
NOTICE: PROPOSED RULES
DOCUMENT ACTION: Notice of proposed rulemaking.
Interpretation of Protection System Reliability Standard
DATES: Comments are due February 25, 2011.
The North American Electric Reliability Corporation (NERC) has submitted a petition (Petition) requesting approval of NERC's interpretation of Requirement R1 of Commissionapproved Reliability Standard PRC0051 (Transmission and Generation Protection System Maintenance and Testing). The Commission proposes to accept the NERC proposed interpretation of Requirement R1 of Reliability Standard PRC 0051, and proposes to direct NERC to develop modifications to the PRC 0051 Reliability Standard, as discussed below, through its Reliability Standards development process to address gaps in the Protection System maintenance and testing standard, highlighted by the proposed interpretation.
Interpretation of Protection System Reliability Standard
DOCUMENT BODY 2:
December 16, 2010.
NERC submitted the Petition requesting approval of NERC's
interpretation of Requirement R1 of Commissionapproved Reliability
Standard PRC0051 (Transmission and Generation Protection System
Maintenance and Testing). NERC developed the interpretation in response
to a request for interpretation submitted to NERC by the Regional
Entities Compliance Monitoring Processes Working Group (Working
Group).\1\ The Commission proposes to accept the NERC proposed interpretation of Requirement R1 of Reliability Standard
PRC0051, and proposes to direct NERC to develop modifications to the PRC0051 Reliability Standard, as discussed below, through its Reliability Standards development process to address gaps in the Protection System maintenance and testing standard highlighted by the proposed interpretation, as discussed below. The Commission seeks comments on its proposal.
\1\ The Working Group is a subcommittee of the Regional Entity Management Group which consists of the executive management of the eight Regional Entities.
2. Section 215 of the Federal Power Act (FPA) requires a
Commissioncertified Electric Reliability Organization (ERO) to develop
mandatory and enforceable Reliability Standards, which are subject to
Commission review and approval.\2\ Specifically, the Commission may
approve, by rule or order, a proposed Reliability Standard or
modification to a Reliability Standard if it determines that the
Standard is just, reasonable, not unduly discriminatory or
preferential, and in the public interest.\3\ Once approved, the
Reliability Standards may be enforced by the ERO, subject to Commission oversight, or by the Commission independently.\4\
\2\ 16 U.S.C. 824.
\3\ Id. 824o(d)(2).
\4\ Id. 824o(e)(3).
3. Pursuant to section 215 of the FPA, the Commission established a
process to select and certify an ERO,\5\ and subsequently certified
NERC.\6\ On April 4, 2006, NERC submitted to the Commission a petition
seeking approval of 107 proposed Reliability Standards. On March 16,
2007, the Commission issued a Final Rule, Order No. 693,\7\ approving
83 of the 107 Reliability Standards, including Reliability Standard
PRC0051. In addition, pursuant to section 215(d)(5) of the FPA,\8\
the Commission directed NERC to develop modifications to 56 of the 83 approved Reliability Standards, including PRC0050.\9\
\5\ Rules Concerning Certification of the Electric Reliability Organization; and Procedures for the Establishment, Approval, and Enforcement of Electric Reliability Standards, Order No. 672, FERC Stats. & Regs. ] 31,204, order on reh'g, Order No. 672A, FERC Stats. & Regs. ] 31,212 (2006).
\6\ North American Electric Reliability Corp., 116 FERC
\7\ Mandatory Reliability Standards for the BulkPower System, Order No. 693, FERC Stats. & Regs. ] 31,242, order on reh'g, Order No. 693A, 120 FERC ] 61,053 (2007).
\8\ 16 U.S.C. 824o(d)(5).
\9\ Order No. 693, FERC Stats. & Regs. ] 31,242 at P 1475.
4. NERC's Rules of Procedure provide that a person that is
``directly and materially affected'' by BulkPower System reliability
may request an interpretation of a Reliability Standard.\10\ In
response, the ERO will assemble a team with relevant expertise to
address the requested interpretation and also form a ballot pool.
NERC's Rules of Procedure provide that, within 45 days, the team will
draft an interpretation of the reliability standard and submit it to
the ballot pool. If approved by the ballot pool and subsequently by the
NERC Board of Trustees (Board), the interpretation is appended to the
Reliability Standard and filed with the applicable regulatory authorities for approval.
\10\ NERC Rules of Procedure, Appendix 3A, Reliability Standards Development Procedure, Version 6.1, at 2627 (2007).
II. Reliability Standard PRC0051
5. The purpose of PRC0051 is to ``ensure all transmission and generation Protection Systems affecting the reliability of the Bulk Electric System (BES) are maintained and tested.'' In particular, Requirement R1, requires that:
R1. Each Transmission Owner and any Distribution Provider that owns a transmission Protection System and each Generator Owner that owns a generation Protection System shall have a Protection System maintenance and testing program for Protection Systems that affect the reliability of the BES. The program shall include:
R1.1. Maintenance and testing intervals and their basis.
R1.2. Summary of maintenance and testing procedures.
6. NERC defines ``Protection System'' as follows: ``Protective relays, associated communication systems, voltage and current sensing devices, station batteries and DC control circuitry.'' \11\ \11\ See NERC Glossary of Terms Used in Reliability Standards at http://www.nerc.com/docs/standards/rs/Glossary_of_Terms_ 2010April20.pdf.
III. NERC Proposed Interpretation
7. In the NERC Petition, NERC explains that it received a request from the Working Group for an interpretation of Reliability Standard PRC0051, Requirement R1, addressing five specific questions. Specifically, the Working Group questions and NERC proposed interpretations include:
Request 1: ``Does R1 require a maintenance and testing program for the battery chargers for the `station batteries' that are considered part of the Protection System?''
Response: ``While battery chargers are vital for ensuring `station batteries' are available to support Protection System functions, they are not identified within the definition of `Protection Systems.' Therefore, PRC0051 does not currently require maintenance and testing of battery chargers.''
Request 2: ``Does R1 require a maintenance and testing program for auxiliary relays and sensing devices? If so, what types of auxiliary relays and sensing devices? (i.e., transformer sudden pressure relays).''
Response: ``The existing definition of `Protection System' does not include auxiliary relays; therefore, maintenance and testing of such devices is not explicitly required. Maintenance and testing of such devices is addressed to the degree that an entity's maintenance and testing program for DC control circuits involves maintenance and testing of imbedded auxiliary relays. Maintenance and testing of devices that respond to quantities other than electrical quantities (for example, sudden pressure relays) are not included within Requirement R1.''
Request 3: ``Does R1 require maintenance and testing of transmission line reclosing relays?''
Response: ``No. `Protective Relays' refer to devices that detect and take action for abnormal conditions. Automatic restoration of transmission lines is not a `protective' function.''
Request 4: ``Does R1 require a maintenance and testing program for the DC circuitry that is just the circuitry with relays and devices that control actions on breakers, etc., or does R1 require a program for the entire circuit from the battery charger to the relays to circuit breakers and all associated wiring?''
Response: ``PRC0051 requires that entities (1) address DC control circuitry within their program, (2) have a basis for the way they address this item, and (3) execute the program. Specific additional requirements relative to the scope and/or methods are not
Request 5: ``For R1, what are examples of `associated communications systems' that are part of `Protection Systems' that require a maintenance and testing program?''
Response: ``Associated communication systems'' refer to
communication systems used to convey essential Protection System
tripping logic, sometimes referred to as pilot relaying or teleprotection. Examples include the following:
Communications equipment involved in powerlinecarrier relaying; Communications equipment involved in various types of permissive protection system applications;
Direct transfertrip systems;
Digital communication systems. * * * ''
8. In support of its request for approval, NERC states that it believes that this interpretation both fairly represents the language of the Reliability Standard and clarifies what components should be included in the maintenance and testing programs specified in the requirement. NERC states that this interpretation supports the reliability of the BulkPower System by providing greater clarity regarding the components that make up a Protection System as defined in the NERC Glossary of Terms.
9. NERC states that an interpretation of a Reliability Standard
requirement cannot expand the intent or meaning of the requirement.\12\
As such, NERC states that any modifications to the language in the
requirements must be processed through the NERC Reliability Standards
Development Procedure, Version 6.1. With this in mind, NERC further
states that it must clarify the requirement language in PRC0051a to
provide a complete framework for maintenance and testing of equipment
necessary to ensure the reliability of the Bulk Power System. NERC
states that this activity is already underway in the scope of Project 200717Protection System Maintenance and Testing.\13\
\12\ NERC Request for Approval of Interpretation at 8.
\13\ NERC Project 200717, Protection System Maintenance and Testing proposes to revise the definition of Protection System as ``protective relays which respond to electrical quantities, communication systems necessary for correct operation of protective functions, voltage and current sensing devices providing inputs to protective relays, station dc supply associated with protective functions (including station batteries, battery chargers, and non batterybased dc supply), and control circuitry associated with protective functions through the trip coils(s) of the circuit breakers or other interrupting devices.''
10. The Commission proposes to accept NERC's proposed interpretation of Reliability Standard PRC0051 Requirement R1. As discussed above, NERC's Glossary defines ``Protection System'' as: ``Protective relays, associated communication systems, voltage and current sensing devices, station batteries and DC control circuitry.'' NERC's proposed interpretation essentially identifies what equipment is considered to be a ``protective relay,'' ``associated communication system,'' ``sensing device,'' or ``station battery.'' None of these terms or phrases within the NERC definition of ``Protection System'' are further defined any where else. NERC's interpretation provides further meaning to these phrases, is not inconsistent with the language of the Reliability Standard and, therefore, appears reasonable. Further, the interpretation should assist in providing a consistent understanding of what constitutes a ``Protection System'' for those entities that must comply with Reliability Standard PRC0051. Accordingly, we proposed to approve NERC's interpretation.
11. However, we are concerned that the proposed interpretation
highlights a gap in the required Protection System maintenance and
testing pursuant to Requirement R1 of PRC0051.\14\ In support of our
concern, we note that the NERC Glossary includes protective relays
within the definition of Protection System. As discussed below, we
believe that all components that serve in some protective capacity to
ensure reliable operation of the BulkPower System should be included
within the definition of ``Protection System'' and should be maintained
and tested accordinglynot just the limited subset identified in the
NERC interpretation. We note that NERC's practice prior to mandatory
and enforceable Reliability Standards included such elements, and we
believe that that understanding should be restored in either the
definition or the Reliability Standard. In particular, prior to the
Version 0 standards, NERC's Compliance Template for NERC Planning
Standard III.A.M4System Protection and Control, Transmission
Protection System, S4 (Protection system maintenance and testing programs shall be developed and implemented) stated that
``[t]ransmission system protection identification [components] shall include, but are not limited to; relays, instrument transformers, communication systems where appropriate, and batteries'' (emphasis added).\15\ The ``but are not limited to'' language was not translated into the Version 0 Reliability Standards that were filed for Commission approval. In addition to NERC's Glossary definition, the Institute of Electronics and Electrical Engineers (IEEE) defines ``protective relay'' as a relay whose ``function is to detect defective lines or apparatus or other power system conditions of an abnormal or dangerous nature and to initiate appropriate control circuit action.'' Therefore, to prevent a gap in reliability, any component that detects any quantity needed to take an action, or that initiates any control action (initial tripping, reclosing, lockout, etc.) affecting the reliability of the BulkPower System should be included as a component of a Protection System. Accordingly, to address our concern, pursuant to section 215(d)(5) of the FPA, we propose to direct NERC to develop a modification to the Reliability Standard to include any component or device that is designed to detect defective lines or apparatuses or other power system conditions of an abnormal or dangerous nature and to initiate appropriate control circuit actions.
\14\ Because the term ``Protection System'' is present in other approved Reliability Standards, the interpretation affects other Reliability Standards not addressed within the scope of the proposed interpretation.
\15\ The Requirement R1.1 provisions in the development of the Version 0 definition of Protection System maintenance and testing program requirements included:
R1.1. Transmission protection system identification shall include but are not limited to (emphasis added):
R1.1.2. Instrument transformers.
R1.1.3. Communications systems, where appropriate.
R1.2. Documentation of maintenance and testing intervals and their basis.
R1.3. Summary of testing procedure.
R1.4. Schedule for system testing.
R1.5. Schedule for system maintenance.
R1.6. Date last tested/maintained.
A. Request 2
12. In response to Request 2, NERC stated that the existing definition of ``Protection System'' ``does not include auxiliary relays,'' and that auxiliary relays need only be maintained if an entity's maintenance and testing program ``for DC control circuits involves maintenance and testing of imbedded auxiliary relays.'' Further, the interpretation excludes the maintenance of all devices that ``respond to quantities other then electrical quantities'' and, specifically, sudden pressure relays. We are concerned that these exclusions contradict the purpose statement of PRC0051, which provides that ``all transmission and generation Protection Systems affecting the reliability of the BES are maintained and tested,'' and, as discussed below, will result in a gap in the maintenance and testing of Protection Systems affecting the reliability of the BulkPower System.
13. If auxiliary relays are included within the Protection System,
in conjunction with other protective relays (e.g., as a contact
multiplier or interface between dissimilar protective systems), or as
part of the Protection System scheme (e.g., as the relay that initiates
a protective action for BulkPower System elements), they must be
maintained and tested to prevent a gap in the reliability affecting the
BulkPower System. This requirement is consistent with NERC's
recommendation of Protection System components specified for performance
tests based on NERC's historical standards, and experience from system events.\16\ Components include protective relays, AC current and voltage sources, communication channel, DC control circuitry, auxiliary relay, breaker trip coil, and DC source as components of a Protection System. This requirement is also consistent with the Commission's understanding of the term ``protective relay'' used in the NERC Glossary definition of Protection System as including all of the individual devices that are either programmed or set to respond to specific conditions, provide input as to the status of facilities, provide or receive signals from communication channels, and initiate actions as required to assure faults, other abnormal conditions, and any other automatic action associated with a fault or abnormal action intended to assure reliability. Auxiliary relays that are used either within the DC control circuitry of a Protection System or in conjunction with other Protective System components,\17\ such as those used as part of the communication channels to provide or receive signals to interface with the DC control circuitry, and are necessary for the correct operation of the Protection System, and the failure to maintain the auxiliary relay will result in a gap in the maintenance and testing of Protection System affecting the reliability of the Bulk Power System.
\16\ See NERC Protection System Maintenance, A Technical Reference, September 13, 2007; NERC Protection System Reliability, Redundancy of Protection System Elements, November 2008.
\17\ Such auxiliary relays may include lockout relays, timer relays, breaker status relays, and transfer trip output contacts which form the necessary logic and decisions of the Protection System that ultimately result in a trip or reclose of a BulkPower System element through the trip coil(s) of the circuit breaker or other interrupting devices.
14. As noted previously, we also are concerned that the proposed interpretation excludes nonelectrical sensing relays. ``Protective relays'' are listed as a component in the NERC definition of ``Protection System.'' Under a plain reading, the term ``protective'' describes a relay that serves to protect the Reliable Operation of the BulkPower System, and thus includes all relays with no stipulation or requirements on device inputs. Some protective relays that do not respond to electric quantities (e.g., sudden pressure relays) nevertheless should be considered as part of the Protection System because they can be crucial for ensuring reliable operation. If a component is designed to sense or take action against an abnormal system condition that will affect the reliable operation of the Bulk Power System, excluding that component results in a gap in the maintenance and testing of relays affecting the reliability of the BulkPower System. Accordingly, pursuant to section 215(d)(5) of the FPA, we propose that NERC propose a modification to the Reliability Standard to address our concern. Specifically, we propose to direct NERC to include any device, including auxiliary and backup protection devices, that is designed to sense or take action against any abnormal system condition that will affect reliable operation.
B. Request 3
15. In request 3, the Working Group asks whether Requirement R1
requires maintenance and testing of transmission line reclosing
relays. Reclosing relays are typically used on the BulkPower System to
address concerns with system stability, system security, or continuity
of service, and must be maintained to ensure correct operation.\18\ In
addition, because the operation of such highspeed reclosing relays is
usually automatic and within one second of the tripping of the Bulk
Power System element,\19\ the operation of these relays must also be
coordinated with the initial tripping of the BulkPower System element.
A misoperating or miscoordinated reclosing relay may result in the
reclosure of a BulkPower System element back onto a fault or that a
misoperating or miscoordinated reclosing relay may fail to operate
after a fault has been cleared, thus failing to restore the element to
service. As a result, not only is damage to the BulkPower System
element a concern, but where misoperation and miscoordination is an
issue, the stability/reliability of the BulkPower System is
threatened. While a reclosing relay is not identified as a specific
component of the Protection System, if it either is used in
coordination with a Protection System to achieve or meet system
performance requirements established in other Commissionapproved
Reliability Standards,\20\ or can exacerbate fault conditions when not
properly maintained and coordinated,\21\ we are concerned that
excluding the maintenance and testing of these reclosing relays will
result in a gap in the maintenance and testing of relays affecting the
reliability of the BulkPower System. Accordingly, pursuant to section
215(d)(5) of the FPA, we propose that NERC propose a modification to
the Reliability Standard to include the maintenance and testing of
reclosing relays affecting the reliability of the BulkPower System.
\18\ We further note that the operation of reclosing relays are
also used in the derivation of Interconnection Reliability Operating
Limits (IROLs) if high speed reclosing is part of the protection
scheme associated with the transmission lines, which system
operators use in realtime to maintain reliable operation of the BulkPower System.
\19\ Highspeed reclosing is generally not used for certain BulkPower System elements, fault types, and conditions, e.g., transformers and underground cables.
\20\ For example, they may be needed to meet the performance requirement of the TPL (transmission planning) Reliability Standards.
\21\ One such outage occurred in ReliabilityFirst resulting in the loss of over 4,000 MW of generation and multiple 765 kV lines. C. Request 4
16. In Request 4, the Working Group asks whether maintenance and testing of the entire DC control circuitry is required under Requirement R1. As discussed above, we understand that maintenance and testing of DC control circuitry includes all components of DC control circuitry necessary for ensuring Reliable Operation. For a Protection System to operate reliably, the DC control circuitry must both have appropriate current carrying capability and be insulated sufficiently to maintain appropriate voltages within the protection system. We are concerned that not establishing the specific requirements relative to the scope and/or methods for a maintenance and testing program for the DC circuitry results in a gap in the maintenance and testing of Protection System components affecting the reliability of the Bulk Power System. Accordingly, pursuant to section 215(d)(5) of the FPA, we propose to direct NERC to develop a modification to the Reliability Standard to address our concern. Specifically, we propose to direct NERC to develop a modification to the Reliability Standard that explicitly includes maintenance and testing of all DC control circuitry that is necessary to ensure proper operation of the Protection System, including voltage and continuity.
17. As discussed above, we propose to accept the proposed interpretation. However, we are concerned that there are gaps in Protection System maintenance and testing, as highlighted by the interpretation. To address our concerns, the Commission proposes to direct NERC to develop modifications to the PRC0051 Reliability Standards through its Reliability Standards development process. [[Page 81156]]
V. Information Collection Statement
18. The Office of Management and Budget (OMB) regulations require
that OMB approve certain reporting and recordkeeping (collections of
information) imposed by an agency.\22\ The information contained here
is also subject to review under section 3507(d) of the Paperwork Reduction Act of 1995.\23\
\22\ 5 CFR 1320.11.
\23\ 44 U.S.C. 3507(d).
19. As stated above, the Commission previously approved, in Order No. 693, the Reliability Standard that is the subject of the current Notice of Proposed Rulemaking (NOPR). This NOPR accepts an interpretation of the currently approved Reliability Standard and does not change this standard. The interpretation of the current Reliability Standard at issue in this rulemaking is not expected to change the reporting burden nor impose any additional information collection requirements.
20. For the purposes of reviewing this interpretation, the Commission seeks information concerning whether the interim interpretation as approved will cause respondents to alter reporting frequencies and potentially impose an additional burden.
21. We will submit this proposed rule to OMB for informational purposes.
Title: Mandatory Reliability Standards for the BulkPower System.
Action: Proposed Collection.
OMB Control No.: 19020244.
Respondents: Businesses or other forprofit institutions; notfor profit institutions.
Frequency of Responses: On Occasion.
Necessity of the Information: This proposed rule would approve an interpretation of the specific requirements of a Commissionapproved Reliability Standard. The proposed rule would find the interpretation just, reasonable, not unduly discriminatory or preferential, and in the public interest.
22. Interested persons may obtain information on the reporting requirements by contacting the following: Federal Energy Regulatory Commission, 888 First Street, NE., Washington, DC 20426 [Attention: Ellen Brown, Office of the Executive Director, phone: (202) 5028663, fax: (202) 2730873, email: firstname.lastname@example.org]. 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 (202) 3957345, fax: (202) 3957285, email: email@example.com]. VI. Environmental Analysis
23. 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.\24\ The
Commission has categorically excluded certain actions from this
requirement as not having a significant effect on the human
environment. Included in the exclusion are rules that are clarifying,
corrective, or procedural or that do not substantially change the
effect of the regulations being amended.\25\ The actions proposed
herein fall within this categorical exclusion in the Commission's regulations.
\24\ Regulations Implementing the National Environmental Policy Act, Order No. 486, FERC Stats. & Regs. ] 30,783 (1987).
\25\ 18 CFR 380.4(a)(2)(ii).
VII. Regulatory Flexibility Act
24. The Regulatory Flexibility Act of 1980 (RFA) \26\ generally
requires a description and analysis of final rules that will have
significant economic impact on a substantial number of small entities.
The RFA mandates consideration of regulatory alternatives that
accomplish the stated objectives of a proposed rule and that minimize
any significant economic impact on a substantial number of small
entities. The Small Business Administration's (SBA) Office of Size
Standards develops the numerical definition of a small business.\27\
The SBA has established a size standard for electric utilities, stating
that a firm is small if, including its affiliates, it is primarily
engaged in the transmission, generation and/or distribution of electric
energy for sale and its total electric output for the preceding twelve
months did not exceed four million megawatt hours.\28\ The RFA is not
implicated by this NOPR because the interpretation discussed herein is
being accepted. With no changes to the Reliability Standard as
approved, the proposal in this NOPR will not have a significant economic impact on a substantial number of small entities.
\26\ 5 U.S.C. 601612.
\27\ 13 CFR 121.201.
\28\ Id. n.1.
25. In Order No. 693, the Commission adopted policies to minimize
the burden on small entities, including approving the ERO compliance
registry process to identify those entities responsible for complying
with mandatory and enforceable Reliability Standards. The ERO registers
only those distribution providers or load serving entities that have a
peak load of 25 MW or greater and are directly connected to the bulk
electric system or are designated as a responsible entity as part of a
required underfrequency load shedding program or a required under
voltage load shedding program. Similarly, for generators, the ERO
registers only individual units of 20 MVA or greater that are directly
connected to the bulk electric system, generating plants with an
aggregate rating of 75 MVA or greater, any blackstart unit material to
a restoration plan, or any generator that is material to the
reliability of the BulkPower System. Further, the ERO will not
register an entity that meets the above criteria if it has transferred
responsibility for compliance with mandatory Reliability Standards to a
joint action agency or other organization. The Commission estimated
that the Reliability Standards approved in Order No. 693 would apply to
approximately 682 small entities (excluding entities in Alaska and
Hawaii), but also pointed out that the ERO's Compliance Registry
Criteria allow for a joint action agency, generation and transmission
(G&T) cooperative or similar organization to accept compliance
responsibility on behalf of its members. Once these organizations
register with the ERO, the number of small entities registered with the
ERO will diminish and, thus, significantly reduce the impact on small entities.\29\
\29\ To be included in the compliance registry, the ERO determines whether a specific small entity has a material impact on the BulkPower System. If these small entities should have such an impact then their compliance is justifiable as necessary for Bulk Power System reliability.
26. Finally, as noted above, this NOPR accepts the interpretation of the PRC0050 Reliability Standard, which was already approved in Order No. 693, and, therefore, does not create an additional regulatory impact on small entities.
VIII. Comment Procedures
27. 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 February 25, 2011. You may submit
comments, identified by docket number and in accordance with the
requirements posted on the Commission's Web site, http://www.ferc.gov. Comments may be
submitted by any of the following methods:
28. All comments will be placed in the Commission's public files and may be viewed, printed, or downloaded remotely as described in the Document Availability section below. Commenters on this proposal are not required to serve copies of their comments on other commenters. IX. Document Availability
29. 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.
30. From FERC's Home Page on the Internet, this information is available on eLibrary. The full text of this document is available on eLibrary in PDF and Microsoft Word format for viewing, printing, and/or downloading. To access this document in eLibrary, type the docket number excluding the last three digits of this document in the docket number field.
31. User assistance is available for eLibrary and the FERC's Web
site during normal business hours from FERC Online Support at 202502 6652 (toll free at 18662083676) or email at
firstname.lastname@example.org, or the Public Reference Room at (202) 502 8371, TTY (202) 5028659. Email the Public Reference Room at email@example.com. List of Subjects in 18 CFR Part 40
Electric power; Electric utilities; Reporting and recordkeeping requirements by direction of the Commission.
Kimberly D. Bose,
[FR Doc. 201032356 Filed 122310; 8:45 am]
BILLING CODE 671701P
FOR FURTHER INFORMATION CONTACT
Ron LeComte (Legal Information), Office of the General Counsel, 888 First Street, NE., Washington, DC 20426. 2025028405. Ron.firstname.lastname@example.org.
Danny Johnson (Technical Information), Office of Electric Reliability, Division of Reliability Standards, 888 First Street, NE., Washington, DC 20426. 2025028892. Danny.email@example.com.