Relay Performance During Stable Power Swings Reliability Standard, 15635-15641 [2016-06508]
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[Docket No. RM15–8–000; Order No. 823]
Authority: 50 U.S.C. 4601 et seq.; 50
U.S.C. 1701 et seq.; 22 U.S.C. 3201 et seq.;
42 U.S.C. 2139a; 22 U.S.C. 7201 et seq.; 22
U.S.C. 7210; E.O. 12058, 43 FR 20947, 3 CFR,
1978 Comp., p. 179; E.O. 12851, 58 FR 33181,
3 CFR, 1993 Comp., p. 608; E.O. 12938, 59
FR 59099, 3 CFR, 1994 Comp., p. 950; E.O.
12947, 60 FR 5079, 3 CFR, 1995 Comp., p.
356; E.O. 13026, 61 FR 58767, 3 CFR, 1996
Comp., p. 228; E.O. 13099, 63 FR 45167, 3
CFR, 1998 Comp., p. 208; E.O. 13222, 66 FR
44025, 3 CFR, 2001 Comp., p. 783; E.O.
13224, 66 FR 49079, 3 CFR, 2001 Comp., p.
786; Notice of August 7, 2015, 80 FR 48233
(August 11, 2015); Notice of September 18,
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Relay Performance During Stable
Power Swings Reliability Standard
Federal Energy Regulatory
Commission, DOE.
ACTION: Final rule.
AGENCY:
The Federal Energy
Regulatory Commission approves
Reliability Standard PRC–026–1 (Relay
Performance During Stable Power
Swings), submitted by the North
American Electric Reliability
Corporation. Reliability Standard PRC–
SUMMARY:
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15635
026–1 is designed to ensure that
applicable entities use protective relay
systems that can differentiate between
faults and stable power swings.
DATES: This rule will become effective
May 23, 2016.
FOR FURTHER INFORMATION CONTACT:
Kenneth Hubona (Technical
Information), Office of Electric
Reliability, Federal Energy Regulatory
Commission, 888 First Street NE.,
Washington, DC 20426, (301) 665–
1608, kenneth.hubona@ferc.gov.
Kevin Ryan (Legal Information), Office
of the General Counsel, Federal
Energy Regulatory Commission, 888
First Street NE., Washington, DC
20426, (202) 502–6840, kevin.ryan@
ferc.gov.
SUPPLEMENTARY INFORMATION:
Order No. 823
Final Rule
1. Pursuant to section 215 of the
Federal Power Act (FPA), the
Commission approves Reliability
Standard PRC–026–1 (Relay
Performance During Stable Power
Swings).1 The North American Electric
Reliability Corporation (NERC), the
Commission-certified Electric
Reliability Organization (ERO),
developed and submitted Reliability
Standard PRC–026–1 for Commission
approval. Reliability Standard PRC–
026–1 applies to planning coordinators
and to generator owners and
transmission owners that apply certain
load-responsive protective relays in
specific, identified circumstances.
Reliability Standard PRC–026–1 is
designed to ensure the use of protective
relay systems that can differentiate
between faults and stable power swings.
2. The Commission determines that
Reliability Standard PRC–026–1
satisfies the directive in Order No. 733
concerning undesirable relay operation
due to power swings.2 The Commission
concludes that Reliability Standard
PRC–026–1 provides an equally
effective and efficient alternative to the
Order No. 733 directive requiring the
use of protective relay systems that can
differentiate between faults and stable
power swings and, when necessary,
retirement of protective relay systems
that cannot meet this requirement.3
3. The Commission approves NERC’s
assigned violation risk factors, violation
1 16
U.S.C. 824o.
Relay Loadability Reliability
Standard, Order No. 733, 130 FERC ¶ 61,221, at P
153 (2010), order on reh’g and clarification, Order
No. 733–A, 134 FERC ¶ 61,127, order on reh’g and
clarification, Order No. 733–B, 136 FERC ¶ 61,185
(2011).
3 Id. P 150.
2 Transmission
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severity levels and implementation
plan.
I. Background
A. Mandatory Reliability Standards and
Order No. 733 Directives
4. Section 215 of the FPA requires a
Commission-certified ERO to develop
mandatory and enforceable Reliability
Standards, subject to Commission
review and approval.4 Pursuant to
section 215 of the FPA, the Commission
established a process to select and
certify an ERO,5 and subsequently
certified NERC.6
5. On March 18, 2010, the
Commission approved Reliability
Standard PRC–023–1 (Transmission
Relay Loadability) in Order No. 733.
The Commission also directed NERC to
develop a new Reliability Standard that
required the use of protective relay
systems that can differentiate between
faults and stable power swings and,
when necessary, the retirement of
protective relay systems that cannot
meet this requirement.7 In Order No.
733, the Commission cited the findings
of both NERC and the U.S.-Canada
Power System Outage Task Force on the
causes of the 2003 Northeast Blackout,
explaining that the cascade during this
event was accelerated by zone 2 and
zone 3 relays that tripped facilities out
of service because these devices could
not distinguish between a dynamic, but
stable, power swing and an actual fault.8
While the Commission recognized that
addressing stable power swings is a
complex issue, Order No. 733 observed
that there was no Reliability Standard to
address relays tripping for stable power
swings despite their contribution to the
2003 Northeast Blackout. Accordingly,
the Commission directed NERC to
develop a Reliability Standard to
address undesirable relay operation due
to stable power swings.9
6. On February 17, 2011, the
Commission denied rehearing in Order
No. 733–A, stating that ‘‘[w]e continue
4 16
U.S.C. 824(d) and (e).
Concerning Certification of the Electric
Reliability Organization; and Procedures for the
Establishment, Approval, and Enforcement of
Electric Reliability Standards, Order No. 672, FERC
Stats. & Regs. ¶ 31,204, order on reh’g, Order No.
672–A, FERC Stats. & Regs. ¶ 31,212 (2006).
6 North American Electric Reliability Corp., 116
FERC ¶ 61,062, order on reh’g and compliance, 117
FERC ¶ 61,126 (2006), aff’d sub nom. Alcoa, Inc.
v. FERC, 564 F.3d 1342 (D.C. Cir. 2009).
7 Order No. 733, 130 FERC ¶ 61,221 at P 150.
8 Id. PP 3–4, 130 (citing U.S.-Canada Power
System Outage Task Force, Final Report on the
August 14, 2003 Blackout in the United States and
Canada: Causes and Recommendations, at 80
(2004); and August 14, 2003 Blackout: NERC
Actions to Prevent and Mitigate the Impacts of
Future Cascading Blackouts, at 13 (2004)).
9 Id. P 153.
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to believe that not addressing stable
power swings constitutes a gap in the
current Reliability Standards and must
be addressed.’’ 10 Accordingly, the
Commission affirmed the directive in
Order No. 733 that NERC develop a
Reliability Standard addressing stable
power swings.11 The Commission
clarified that it did not require a
Reliability Standard containing an
absolute obligation to prevent protection
relays from operating unnecessarily
during stable power swings or an acrossthe-board elimination of all zone 3
relays; the Commission only required
the development of a Reliability
Standard that addresses protection
systems that are vulnerable to stable
power swings (resulting from Category B
and Category C contingencies from the
NERC Planning Standards in place at
that time) that result in inappropriate
tripping.12 In Order No. 733–B, the
Commission denied further clarification
on this issue.
B. NERC Petition and Reliability
Standard PRC–026–1
7. On December 31, 2014, NERC
submitted a petition seeking approval of
Reliability Standard PRC–026–1, as well
as the associated violation risk factors,
violation severity levels and
implementation plan.13 NERC avers that
Reliability Standard PRC–026–1
satisfies the Order No. 733 directive to
develop a new Reliability Standard that
requires the use of protective relay
systems that can differentiate between
faults and stable power swings.
According to NERC, Reliability
Standard PRC–026–1 sets forth
requirements that prevent the
unnecessary tripping of bulk electric
system elements in response to stable
power swings.14 NERC further explains
that the identification of bulk electric
system elements with protection
systems at-risk of operating as a result
of a stable or unstable power swing and
the subsequent review by the applicable
generator owner or transmission owner
‘‘provides assurance that relays will
continue to be secure for stable power
swings if any changes in system
impedance occur.’’15
8. According to NERC, Reliability
Standard PRC–026–1 is ‘‘directly
responsive’’ to the Order No. 733
directive that NERC develop a
10 Order
No. 733–A, 134 FERC ¶ 61,127 at P 104.
11 Id.
12 Id.
P 107.
13 Reliability
Standard PRC–026–1 is available on
the Commission’s eLibrary document retrieval
system in Docket No. RM15–8–000 and on the
NERC Web site, www.nerc.com.
14 See NERC Petition at 4.
15 Id.
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Reliability Standard addressing
undesirable relay operation due to
stable power swings.16 However, NERC
explains that the Reliability Standard
PRC–026–1 ‘‘includes an alternative to
the Commission’s approach to require
‘the use of protective relay systems that
can differentiate between faults and
stable power swings and, when
necessary, phases out protective relay
systems that cannot meet this
requirement.’ ’’ 17 NERC notes that in
Order No. 733–A, the Commission
clarified that it had not intended ‘‘to
prohibit NERC from exercising its
technical expertise to develop a solution
to an identified reliability concern that
is equally effective and efficient as the
one proposed in Order No. 733.’’ 18 In
support of its alternative solution, NERC
states that ‘‘it is generally preferable to
emphasize dependability over security
when it is not possible to ensure both
for all possible system conditions.’’ 19
NERC also avers that ‘‘[p]rohibiting use
of certain types of relays, such as those
protective relay systems that cannot
differentiate between faults and stable
power swings, may have unintended
negative outcomes for Bulk-Power
System reliability.’’ 20
9. Reliability Standard PRC–026–1
has four requirements and two
attachments. NERC explains that
Attachment A ‘‘provides clarity on
which load-responsive protective relay
functions are applicable’’ under the
standard.21 Specifically, Attachment A
provides that Reliability Standard PRC–
026–1 applies to:
any protective functions which could trip
instantaneously or with a time delay of less
than 15 cycles on load current (i.e., ‘‘loadresponsive’’). . . .
According to NERC, the 15 cycle time
delay ‘‘is representative of an expected
power swing having a slow slip rate of
0.67 Hertz (Hz) and is the average time
that a stable power swing with that slip
rate would enter the relay’s
characteristic, reverse direction, and
then exit the characteristic before the
time delay expired.’’ 22 NERC states that
the proposed standard does not apply to
‘‘functions that are either immune to
power swings, block power swings, or
prevent non-immune protection
function operation due to supervision of
16 Id. at 23 (citing Order No. 733, 130 FERC ¶
61,221 at P 153).
17 Id. (quoting Order No. 733, 130 FERC ¶ 61,221
at P 162).
18 Id. at 11 (citing Order No. 733–A, 134 FERC ¶
61,127 at P 11).
19 Id. at 24.
20 Id.
21 Id. at 31.
22 Id. at 30.
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the function.’’ 23 Attachment B contains
the criteria for the evaluation of loadresponsive protective relays that are
within the scope of Reliability Standard
PRC–026–1.24
10. Under NERC’s proposed
implementation plan for Reliability
Standard PRC–026–1, Requirement R1
would become effective 12 months after
Commission approval, and
Requirements R2, R3 and R4 become
effective 36 months after Commission
approval.
C. Notice of Proposed Rulemaking
11. On September 17, 2015, the
Commission issued a Notice of
Proposed Rulemaking (NOPR)
proposing to approve Reliability
Standard PRC–026–1 as just, reasonable,
not unduly discriminatory or
preferential and in the public interest.25
The NOPR stated that Reliability
Standard PRC–026–1 appears to
adequately address the Commission’s
directive in Order No. 733 by helping to
prevent the unnecessary tripping of bulk
electric system elements in response to
stable power swings. The NOPR also
proposed to accept NERC’s proposed
approach as an equally effective and
efficient method to achieve the
reliability goal underlying the
Commission’s Order No. 733 directive.
12. In the NOPR, the Commission also
expressed concern that NERC’s
exclusion of load responsive relays with
a time delay of 15 cycles or greater, as
proposed in Attachment A to Reliability
Standard PRC–026–1, could result in a
gap in reliability. The Commission
explained that, pursuant to Attachment
A, Reliability Standard PRC–026–1
applies to ‘‘any protective functions
which could trip instantaneously or
with a time delay of less than 15 cycles
on load current (i.e., ‘‘loadresponsive’’). . . .’’ The Commission
further explained that, although NERC
offered a technical rationale for the less
than 15 cycle threshold, explaining that
load-responsive relays set to trip
instantaneously or with a ‘‘slight time
delay’’ are most susceptible to power
swings, NERC did not supply
information on the burden of including
relays with a time delay of 15 cycles or
greater under Reliability Standard PRC–
026–1.26 The Commission stated that
the lack of this information is significant
in light of the fact that an entity would
23 Id.
at 31.
id. at 35–38.
25 Relay Performance During Stable Power Swings
Reliability Standard, Notice of Proposed
Rulemaking, 80 FR 57549 (Sept. 24, 2015), 152
FERC ¶ 61,200 (2015).
26 See NOPR, 152 FERC ¶ 61,200 at P 14 (citing
NERC Petition at 29–30).
24 See
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not be required under Reliability
Standard PRC–026–1 to investigate an
element identified by a planning
coordinator as potentially susceptible to
power swings or investigate an element
following a known power swing trip if
the relay(s) involved have a time delay
of 15 cycles or greater.27
13. The NOPR requested comments
on the potential burden of modifying
the applicability of Reliability Standard
PRC–026–1 to include relays with a
time delay of 15 cycles or greater in
instances where either: (1) An element
has been identified by a planning
coordinator as potentially susceptible to
power swings; or (2) an entity becomes
aware of a bulk electric system element
that tripped in response to a stable or
unstable power swing due to the
operation of its protective relay(s), even
if the element was not previously
identified by the planning coordinator.
The Commission stated that it may
direct NERC to develop modifications to
Reliability Standard PRC–026–1
depending on the response to the
questions on the applicability of
Reliability Standard PRC–026–1.
14. In response to the NOPR, seven
entities submitted comments. A list of
commenters appears in Appendix A.
The comments have informed our
decision making in this Final Rule.
II. Discussion
15. Pursuant to section 215(d)(2) of
the FPA, we approve Reliability
Standard PRC–026–1 as just, reasonable,
not unduly discriminatory or
preferential, and in the public interest.
We also approve NERC’s proposed
violation risk factors, violation severity
levels and implementation plan. While
Reliability Standard PRC–026–1 does
not prohibit the use of relays that cannot
differentiate between faults and stable
power swings, Reliability Standard
PRC–026–1 addresses the prevention of
unnecessary tripping of bulk electric
system elements in response to stable
power swings. Accordingly, we approve
NERC’s approach as an equally effective
and efficient method to achieve the
reliability goal underlying the
Commission’s directive in Order No.
733.
16. As discussed below, based on the
NOPR comments, we conclude that the
potential reliability gap identified in the
NOPR, resulting from the exclusion of
load responsive relays with a time delay
of 15 cycles or greater as proposed in
Attachment A to Reliability Standard
PRC–026–1, is adequately addressed by
27 Id.
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15637
the provisions of Reliability Standards
TPL–001–4 and PRC–004–4.28
Load Responsive Relays With a Delay of
15 Cycles or Greater
Comments
17. NERC, Luminant, NAGF, TriState, Idaho Power and EEI support the
Commission’s proposal to approve
Reliability Standard PRC–026–1. In
response to the NOPR’s question
regarding the burden of expanding the
applicability of Reliability Standard
PRC–026–1 to include load responsive
relays with a time delay of 15 cycles or
greater, NERC and other commenters
offer two responses. First, commenters
maintain that the 15 cycle limitation in
Reliability Standard PRC–026–1 does
not result in a reliability gap because of
how Reliability Standard PRC–026–1
interacts with other Reliability
Standards to address the Commission’s
concern. Second, commenters assert
that expanding the applicability of
Reliability Standard PRC–026–1 would
result in an unnecessary, significant
burden or risk to reliability.
18. NERC, EEI, Tri-State and
Luminant claim that no reliability gap
results from the 15 cycle limitation in
Reliability Standard PRC–026–1 because
planning assessments required by
Reliability Standard TPL–001–4 already
address the Commission’s concerns
regarding relays with a time delay of 15
cycles or greater in instances where an
element has been identified by a
planning coordinator as potentially
susceptible to power swings.29
Specifically, NERC explains that a
planning assessment conducted
pursuant to Reliability Standard TPL–
001–4 ‘‘will reveal Elements with loadresponsive protective relays having time
delays of 15 cycles or greater that trip
due to power swings.’’ 30 NERC further
contends that, where an element that
trips causes a violation of Reliability
Standard TPL–001–4 performance
criteria, ‘‘the Planning Coordinator is
required to mitigate these conditions
through a Corrective Action Plan.’’ 31
EEI agrees with NERC’s assessment and
identifies Reliability Standard TPL–
001–4, Requirement R4, Subpart 4.1.2
and Requirement R2, Subpart 2.7 as the
corresponding requirements.32
28 As of January 1, 2016, all requirements of
Reliability Standard TPL–001–4 are subject to
enforcement. Reliability Standard PRC–004–4 was
approved May 29, 2015 and will be subject to
enforcement July 1, 2016.
29 NERC Comments at 5–6. See also Tri-State
Comments at 4; Luminant Comments at 3.
30 NERC Comments at 6.
31 Id.
32 EEI Comments at 7.
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19. In addition, NERC and industry
commenters state that Reliability
Standard PRC–004–4 addresses the
Commission’s concern regarding
situations where a bulk electric system
element trips in response to a stable or
unstable power swing due to the
operation of its protective relay(s).33
Specifically, NERC explains that
tripping unnecessarily ‘‘due to an actual
stable power swing would be classified
as a Misoperation under PRC–004–4
(Protection System Misoperation
Identification and Correction).’’ 34 NERC
explains that a ‘‘Generator Owner and
Transmission Owner are required to
develop a corrective action plan to
address the cause(s) of the
Misoperation, for example, tripping due
to a load-responsive protective relay set
with a time delay of 15 cycles or greater,
unless reliability would not be
improved.’’ 35
20. Regarding the potential burden of
expanding the applicability of
Reliability Standard PRC–026–1 to
cover relays with a time delay of 15
cycles or greater, NERC and industry
commenters state that expanding the
applicability of Requirement R1, Criteria
4 (element has been identified by a
planning coordinator) would increase
the burden on transmission owners and
generator owners.36 NERC states that
there would be no increase in burden
for the planning coordinator because the
planning coordinator is required by
Reliability Standard TPL–001–4,
Requirement R4 ‘‘to perform
contingency analyses based on
computer simulation models for the
Stability portion of the annual Planning
Assessment.’’ 37 As noted above, NERC
explains that where an element that
trips during the annual planning
assessment causes a violation of
Reliability Standard TPL–001–4
performance criteria, ‘‘the Planning
Coordinator is required to mitigate these
conditions through a Corrective Action
Plan.’’ 38
21. NERC, however, states that
expanding the applicability of
Reliability Standard PRC–026–1 to
cover relays with a time delay of 15
cycles or greater would ‘‘place
additional burden on the Generator
Owner and Transmission Owner for any
Elements that are identified using
33 NERC Comments at 9–10. See also EEI
Comments at 8; Tri-State Comments at 5.
34 NERC Comments at 9.
35 Id.
36 See id. at 7, 9. See also EEI Comments at 6;
Luminant Comments at 4; Idaho Power Comments
at 2.
37 NERC Comments at 5.
38 Id.
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Requirement R1, Criteria 4.’’ 39 NERC
explains that the additional burden
‘‘would be determined by the increase
in the quantity of load-responsive
protective relays applied to that Element
beyond what is proposed in PRC–026–
1 (i.e. load-responsive protective relays
with time delays of 15 cycles or
greater).’’ NERC continues that the
‘‘increase in burden could be on the
order of two to three times in magnitude
to address zone 2 (not communicationaided) and application of reverse zone
and/or forward zone 4 remote back-up
time delayed elements.’’ 40
22. EEI contends that the additional
burden would ‘‘vary greatly by entity
size and asset configuration, however,
the work associated with this effort
would not be inconsequential and
would consume significant dollars for
large entities while tying up critical and
often scarce engineering resources
across the industry.’’ 41 EEI explains that
even though the Commission proposes
to limit the analysis to the two scenarios
identified in the NOPR, the proposal
would increase the number of relay
elements evaluated by 100 to 200
percent at impacted transmission lines,
generators and transformer terminals.42
23. ITC, while not taking a position on
the merits of the particular requirements
of Reliability Standard PRC–026–1,
argues ‘‘that studies and information
now available concerning relay
performance during stable power swings
controvert the Commission’s at-the-time
reasonable determination in Order No.
733 that a Standard to address relay
performance during stable power swings
was warranted.’’ 43 In particular, ITC
‘‘urge[s] the Commission to consider the
[NERC System Protection and Control
Subcommittee] Report findings in
issuing its final rule in this
proceeding.’’ 44 ITC asserts that the
SPSC Report undercuts the rationale for
promulgating Reliability Standard PRC–
026–1 and argues that ‘‘the Commission
should reconsider the necessity of PRC–
026–1, particularly in light of the
burden NERC has determined the new
Standard would impose.’’ 45
Commission Determination
24. We find that Reliability Standard
PRC–026–1 addresses the Commission’s
directive in Order No. 733 by providing
measures to mitigate the unnecessary
39 Id.
at 6.
at 7.
41 EEI Comments at 6.
42 Id.
43 ITC Comments at 3.
44 Id. (referencing NERC System Protection and
Control Subcommittee, ‘‘Protection System
Response to Power Swings’’ (2013) (SPSC Report)).
45 Id. at 4.
40 Id.
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tripping of bulk electric system
elements in response to stable power
swings. While it does not prohibit the
use of relays that cannot differentiate
between faults and stable power swings,
we conclude that Reliability Standard
PRC–026–1’s approach is an equally
effective and efficient method to achieve
the reliability goal underlying the
Commission’s directive in Order No.
733.
25. While ITC asks that the
Commission reconsider the necessity of
PRC–026–1 in light of the SPSC Report,
the Commission continues to believe in
the necessity of a Reliability Standard
that addresses the performance of relays
during stable power swings. In response
to ITC’s comments, the
recommendations from the 2013 SPSC
Report were used in the development of
Reliability Standard PRC–026–1. As
noted by NERC, Reliability Standard
PRC–026–1 ‘‘is based on and is
consistent with the recommendations
found in the [SPSC] Report.’’ 46
Accordingly, we conclude that
Reliability Standard PRC–026–1 reflects
the recommendations outlined in the
SPSC Report.
26. Based on the NOPR comments, we
are persuaded that the potential
reliability gap identified in the NOPR,
resulting from the exclusion of load
responsive relays with a time delay of
15 cycles or greater as proposed in
Attachment A to Reliability Standard
PRC–026–1, is adequately addressed by
requirements of Reliability Standards
TPL–001–4 (Transmission System
Planning Performance Standards) and
PRC–004–4 (Protection System
Misoperation Identification and
Correction). We agree with commenters
that these Reliability Standards
adequately address the risk posed by
load responsive relays with a time delay
of 15 cycles or greater in the two cases
identified in the NOPR. Accordingly, we
do not direct any modifications to
Reliability Standard PRC–026–1 at this
time.
27. First, where an element has been
identified by a planning coordinator as
potentially susceptible to power swings,
Reliability Standard TPL–001–4
addresses the NOPR’s concern by
requiring applicable entities to both (1)
identify elements with load-responsive
protective relays having time delays of
15 cycles or greater that trip due to
power swings and (2) mitigate through
a corrective action plan where
Reliability Standard TPL–001–4
performance criteria are not met.
Specifically, Reliability Standard TPL–
001–4 sets forth the parameters for
46 NERC
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certain studies associated with the
annual planning assessment that are
intended to identify, among other
things, situations where a transmission
system element trips due to an
impedance swing resulting from a
generator pulling out of
synchronization.47 An element that trips
due to the criteria in Requirement R4,
Subpart 4.1.2 fails to meet the
performance requirements in Table 1 of
Reliability Standard TPL–001–4. When
an element fails to meet the
performance requirements in Table 1,
the planning coordinator is required to
develop a ‘‘Corrective Action Plan(s)
addressing how the performance
requirements will be met.’’ 48 Therefore,
Reliability Standard TPL–001–4
addresses the concerns raised in the
NOPR regarding the exclusion of load
responsive relays with a time delay of
15 cycles or greater from Requirement
R1 of Reliability Standard PRC–026–1.
28. Second, where an entity becomes
aware of a bulk electric system element
that tripped in response to a stable or
unstable power swing due to the
operation of its protective relay(s), we
agree with commenters that the tripping
would be classified as a misoperation
under Reliability Standard PRC–004–
4.49 Therefore, the generator owner or
transmission owner would be required
to develop a corrective action plan to
address the cause(s) of the misoperation,
which in this case would be tripping
due to a load-responsive protective relay
set with a time delay of 15 cycles or
greater, unless the transmission owner
or generation owner ‘‘explains in a
declaration why corrective action plans
are beyond the entity’s control or would
not improve BES reliability.’’ 50
Specifically, Reliability Standard PRC–
004–4 requires entities to investigate
and mitigate, through a corrective action
plan, any misoperation.51 A
misoperation under Reliability Standard
PRC–004–4 includes, in pertinent part,
unnecessary trips for non-fault
conditions resulting from power
swings.52 Therefore, Reliability
Standard PRC–004–4 addresses the
concerns raised in the NOPR regarding
the exclusion of load responsive relays
with a time delay of 15 cycles or greater
from Requirement R2, Part 2.2 of
Reliability Standard PRC–026–1.
29. Finally, concerns with the
potential burden of expanding the
applicability of Reliability Standard
PRC–026–1 to cover relays with a time
delay of 15 cycles or greater in order to
address the potential reliability gap
identified in the NOPR are moot given
our determination above that the
potential reliability gap identified in the
NOPR is adequately addressed by
existing Reliability Standard
requirements.
III. Information Collection Statement
30. The FERC–725G 53 information
collection requirements contained in
this Final Rule are subject to review by
the Office of Management and Budget
(OMB) regulations under section
3507(d) of the Paperwork Reduction Act
of 1995 (PRA).54 OMB’s regulations
require approval of certain
informational collection requirements
imposed by agency rules.55 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 a rule will not be
penalized for failing to respond to these
collections of information unless the
collections of information display a
valid OMB control number.
31. The Commission solicited
comments on the need for this
information, whether the information
will have practical utility, the accuracy
of the burden estimates, ways to
enhance the quality, utility, and clarity
of the information to be collected or
52 Id.,
Reliability Standard TPL–001–4
(Transmission System Planning Performance
Requirements), Requirement R4, Subpart 4.1.2.
48 Id., Requirement R2, Subpart 2.7.
49 See, e.g., NERC Comments at 9–10, EEI
Comments at 8.
50 Reliability Standard PRC–004–4 (Protection
System Misoperation and Correction), Requirement
R5.
51 See id.
asabaliauskas on DSK3SPTVN1PROD with RULES
47 See
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Application Guidelines at 22.
requirements in the RM15–8–000 NOPR
were submitted to OMB within FERC–725G3 (OMB
Control Number 1902–0285). FERC–725G3 is a
temporary collection that enabled timely
submission to OMB. The requirements are now
being submitted to the information collection
intended for these requirements, specifically FERC–
725G (OMB Control No. 1902–0252).
54 44 U.S.C. 3507(d).
55 5 CFR 1320.11.
53 The
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15639
retained, and any suggested methods for
minimizing respondents’ burden,
including the use of automated
information techniques. Specifically,
the Commission asked that any revised
burden or cost estimates submitted by
commenters be supported by sufficient
detail to understand how the estimates
are generated. The Commission did not
receive any comments on the estimates
in the NOPR.
Public Reporting Burden: The
Commission approves Reliability
Standard PRC–026–1. Reliability
Standard PRC–026–1 will impose new
requirements for the notification of
particular bulk electric system elements
from planning coordinator to generator
owners and transmissions owners based
on given criteria. Generator owners and
transmissions owner will evaluate those
bulk electric system elements and loadresponsive protective relay(s) according
to Attachment B criteria and, if a loadresponsive protective relay does not
meet the Attachment B criteria, the
generator owner/transmission owner
must develop a corrective action plan.
Our estimate below regarding the
number of respondents is based on the
NERC Compliance Registry as of June
26, 2015. According to the NERC
Compliance Registry, NERC has
registered 318 transmission owners, 884
generator owners, and 68 planning
coordinators. However, under NERC’s
compliance registration program,
entities may be registered for multiple
functions, so these numbers incorporate
some double counting. The total number
of unique entities that may be identified
as a notification provider (e.g.
applicable entity) in accordance with
proposed Reliability Standard PRC–
026–1 will be approximately 1,074
entities registered in the United States
as a transmission owner and/or
generator owner. The total number of
unique entities that may be identified as
evidence retention entities (e.g.
applicable entity) in accordance with
proposed Reliability Standard PRC–
026–1 will be approximately 1,092
entities registered in the United States
as a transmission owner, generator
owner and/or planning coordinator. The
Commission estimates the annual
reporting burden and cost as follows:
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RM15–8–000 (MANDATORY RELIABILITY STANDARDS—RELIABILITY STANDARD PRC–026–1)
Number of
respondents
Annual
number of
responses per
respondent
Total
number of
responses
Average
burden & cost
per response
Total annual
burden hours
& total
annual cost
Cost per
respondent
($)
(1)
(2)
(1) * (2) = (3)
(4)
(3) * (4) = (5)
(5) ÷ (1)
Notifications to GO/TO per Requirement
R1 .........................................................
1,074
1
1,074
8, $485.28 56
Evidence Retention GO/TO/PC ...............
1,092
1
1,092
12, $450.00 57
Total ..................................................
........................
........................
2,166
........................
asabaliauskas on DSK3SPTVN1PROD with RULES
Title: FERC–725G, Mandatory
Reliability Standards: Reliability
Standard PRC–026–1.
Action: Collection of Information.
OMB Control No: 1902–0252.
Respondents: Business or other forprofit and not-for-profit institutions.
Frequency of Responses: One time
and on-going.
Necessity of the Information:
Reliability Standard PRC–026–1 will
implement the Congressional mandate
of the Energy Policy Act of 2005 to
develop mandatory and enforceable
Reliability Standards to better ensure
the reliability of the nation’s BulkPower System. Specifically, the
Reliability Standard will address
undesirable relay operation due to
power swings.
32. Internal review: The Commission
has reviewed the requirements
pertaining to the Reliability Standard
PRC–026–1 and made a determination
that the requirements of this standard
are necessary to implement section 215
of the FPA. These requirements conform
to the Commission’s plan for efficient
information collection, communication
and management within the energy
industry. The Commission has assured
itself, by means of its internal review,
that there is specific, objective support
for the burden estimates associated with
the information requirements.
56 The estimates for cost per response are derived
using the following formula:
Average Burden Hours per Response * $60.66 per
Hour = Average Cost per Response. The hourly
average of $60.66 assumes equal time is spent by
the manager, electrical engineer, and information
and record clerk. The average hourly cost (salary
plus benefits) is: $37.50 for information and record
clerks (occupation code 43–4199), $78.04 for a
manager (occupation code 11–0000), and $66.45 for
an electrical engineer (occupation code 17–2071).
(The figures are taken from the Bureau of Labor
Statistics, May 2014 figures at https://www.bls.gov/
oes/current/naics2_22.htm.)
57 The average hourly cost (salary plus benefits)
is $37.50. The BLS wage category code is 34–4199.
This figure is also taken from the Bureau of Labor
Statistics, May 2014 figures at https://www.bls.gov/
oes/current/naics2_22.htm.
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33. Interested persons may obtain
information on the reporting
requirements by contacting the Federal
Energy Regulatory Commission, Office
of the Executive Director, 888 First
Street, NE., Washington, DC 20426
[Attention: Ellen Brown, email:
DataClearance@ferc.gov, phone: (202)
502–8663, fax: (202) 273–0873].
34. Comments concerning the
information collections approved in this
Final Rule and the associated burden
estimates, should be sent to the
Commission in this docket and may also
be sent to the Office of Management and
Budget, Office of Information and
Regulatory Affairs [Attention: Desk
Officer for the Federal Energy
Regulatory Commission, phone: (202)
395–0710, fax: (202) 395–7285]. For
security reasons, comments should be
sent by email to OMB at the following
email address: oira_submission@
omb.eop.gov. Please reference the
docket number of this Final Rule
(Docket No. RM15–8–000) in your
submission.
IV. Regulatory Flexibility Act Analysis
35. The Regulatory Flexibility Act of
1980 (RFA) 58 generally requires a
description and analysis of this Final
Rule that will have significant economic
impact on a substantial number of small
entities. Reliability Standard PRC–026–
1 sets forth requirements that prevent
the unnecessary tripping of bulk electric
system elements in response to stable
power swings. As shown in the
information collection section, an
estimated 1,092 entities are expected to
evaluate bulk electric system elements
and load-responsive protective relay(s)
according to Attachment B criteria of
PRC–026–1. Comparison of the
applicable entities with the
Commission’s small business data
indicates that approximately 661 are
58 5
PO 00000
U.S.C. 601–612.
Frm 00028
Fmt 4700
Sfmt 4700
8,592
$521,191
13,104
$491,400
$485.28
21,696
$1,012,591
........................
450.00
small entities 59 or 60.53 percent of the
respondents affected by Reliability
Standard PRC–026–1.
36. As discussed above, Reliability
Standard PRC–026–1 will serve to
enhance reliability by imposing
mandatory requirements governing
generator relay loadability, thereby
reducing the likelihood of premature or
unnecessary tripping of generators
during system disturbances. The
Commission estimates that each of the
small entities to whom the Reliability
Standard PRC–026–1 applies will incur
paperwork and record retention costs of
$935.28 per entity (annual ongoing).
37. The Commission does not
consider the estimated costs per small
entity to have a significant economic
impact on a substantial number of small
entities. Accordingly, the Commission
certifies that Reliability Standard PRC–
026–1 will not have a significant
economic impact on a substantial
number of small entities. Accordingly,
no regulatory flexibility analysis is
required.
V. Environmental Analysis
38. 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.60 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,
59 The Small Business Administration sets the
threshold for what constitutes a small business.
Public utilities may fall under one of several
different categories, each with a size threshold
based on the company’s number of employees,
including affiliates, the parent company, and
subsidiaries. For the analysis in this rule, we apply
a 500 employee threshold for each affected entity.
Each entity is classified as Electric Bulk Power
Transmission and Control (NAICS code 221121).
60 Regulations Implementing the National
Environmental Policy Act of 1969, Order No. 486,
FERC Stats. & Regs. ¶ 30,783 (1987).
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or procedural or that do not
substantially change the effect of the
regulations being amended.61 The
actions herein fall within this
categorical exclusion in the
Commission’s regulations.
VI. Effective Date and Congressional
Notification
39. This Final Rule is effective May
23, 2016. The Commission has
determined, with the concurrence of the
Administrator of the Office of
Information and Regulatory Affairs of
OMB, that this rule is not a ‘‘major rule’’
as defined in section 351 of the Small
Business Regulatory Enforcement
Fairness Act of 1996. This Final Rule is
being submitted to the Senate, House,
and Government Accountability Office.
VII. Document Availability
40. 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 the
Commission’s Home Page (https://
www.ferc.gov) and in the Commission’s
Public Reference Room during normal
business hours (8:30 a.m. to 5:00 p.m.
Eastern time) at 888 First Street NE.,
Room 2A, Washington, DC 20426.
41. From the Commission’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 of this
15641
document, excluding the last three
digits, in the docket number field.
42. User assistance is available for
eLibrary and the Commission’s Web site
during normal business hours from the
Commission’s Online Support at 202–
502–6652 (toll free at 1–866–208–3676)
or email at ferconlinesupport@ferc.gov,
or the Public Reference Room at (202)
502–8371, TTY (202) 502–8659. Email
the Public Reference Room at
public.referenceroom@ferc.gov.
By the Commission.
Issued: March 17, 2016.
Nathaniel J. Davis, Sr.,
Deputy Secretary.
Note: The following Appendix will not
appear in the Code of Federal Regulations.
Appendix
COMMENTERS
Abbreviation
Commenter
EEI ...........................................................
Idaho Power ............................................
ITC ...........................................................
Luminant ..................................................
NERC .......................................................
NAGF .......................................................
Tri-State ...................................................
Edison Electric Institute.
Idaho Power Company.
International Transmission Company.
Luminant Generation Company LLC.
North American Electric Reliability Corporation.
North American Generator Forum.
Tri-State Generation and Transmission Association, Inc.
[FR Doc. 2016–06508 Filed 3–23–16; 8:45 am]
BILLING CODE 6717–01–P
DEPARTMENT OF COMMERCE
International Trade Administration
19 CFR Part 351
[Docket No. 140929814–6136–02]
RIN 0625–AB02
Modification of Regulations Regarding
Price Adjustments in Antidumping
Duty Proceedings
Enforcement and Compliance,
International Trade Administration,
Department of Commerce.
ACTION: Final rule.
AGENCY:
The Department of Commerce
(the Department) is modifying its
regulations pertaining to price
adjustments in antidumping duty
proceedings. These modifications clarify
that the Department does not intend to
accept a price adjustment that is made
after the time of sale unless the
interested party demonstrates, to the
satisfaction of the Department, its
entitlement to such an adjustment. The
asabaliauskas on DSK3SPTVN1PROD with RULES
SUMMARY:
61 18
Department has further adopted in this
final rule a non-exhaustive list of factors
that it may consider in determining
whether to accept a price adjustment
that is made after the time of sale.
DATES: Effective date: April 25, 2016.
Applicability date: This rule will apply
to all proceedings initiated on or after
April 25, 2016.
FOR FURTHER INFORMATION CONTACT:
Jessica Link at (202) 482–1411, James
Ahrens at (202) 482–3558, or Melissa
Skinner at (202) 482–0461.
SUPPLEMENTARY INFORMATION:
Background
Section 731 of the Tariff Act of 1930,
as amended (the Act) provides that
when a company is selling foreign
merchandise into the United States at
less than fair value, and material injury
or threat of material injury is found by
the International Trade Commission, the
Department shall impose an
antidumping duty. An antidumping
duty analysis involves a comparison of
the company’s sales price in the United
States (known as the export price or
constructed export price) with the price
or cost in the foreign market (known as
the normal value). See 19 CFR
351.401(a). See also section 772 of the
Act (defining export price and
constructed export price) and section
773 of the Act (defining normal value).
The prices used to establish export
price, constructed export price, and
normal value involve certain
adjustments. See, e.g., 19 CFR
351.401(b). In its May 19, 1997 final
rulemaking, the Department
promulgated regulatory provisions
governing the use of price adjustments
in the calculation of export price,
constructed export price, and normal
value in antidumping duty proceedings.
Antidumping Duties; Countervailing
Duties; Final Rule, 62 FR 27296 (May
19, 1997) (‘‘1997 Final Rule’’). In
particular, the Department promulgated
the current regulation at 19 CFR
351.102(b)(38), which provides a
definition of ‘‘price adjustment.’’ In
providing this definition, the
Department stated that ‘‘[t]his term is
intended to describe a category of
changes to a price, such as discounts,
rebates and post-sale price adjustments,
that affect the net outlay of funds by the
purchaser.’’ 1997 Final Rule, 62 FR at
27300.
The Department also enacted 19 CFR
351.401(c) that explains how the
Department will use a price net of price
CFR 380.4(a)(2)(ii) (2015).
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]]>Agencies
[Federal Register Volume 81, Number 57 (Thursday, March 24, 2016)]
[Rules and Regulations]
[Pages 15635-15641]
From the Federal Register Online via the Government Publishing Office [www.gpo.gov]
[FR Doc No: 2016-06508]
=======================================================================
-----------------------------------------------------------------------
DEPARTMENT OF ENERGY
Federal Energy Regulatory Commission
18 CFR Part 40
[Docket No. RM15-8-000; Order No. 823]
Relay Performance During Stable Power Swings Reliability Standard
AGENCY: Federal Energy Regulatory Commission, DOE.
ACTION: Final rule.
-----------------------------------------------------------------------
SUMMARY: The Federal Energy Regulatory Commission approves Reliability
Standard PRC-026-1 (Relay Performance During Stable Power Swings),
submitted by the North American Electric Reliability Corporation.
Reliability Standard PRC-026-1 is designed to ensure that applicable
entities use protective relay systems that can differentiate between
faults and stable power swings.
DATES: This rule will become effective May 23, 2016.
FOR FURTHER INFORMATION CONTACT:
Kenneth Hubona (Technical Information), Office of Electric Reliability,
Federal Energy Regulatory Commission, 888 First Street NE., Washington,
DC 20426, (301) 665-1608, kenneth.hubona@ferc.gov.
Kevin Ryan (Legal Information), Office of the General Counsel, Federal
Energy Regulatory Commission, 888 First Street NE., Washington, DC
20426, (202) 502-6840, kevin.ryan@ferc.gov.
SUPPLEMENTARY INFORMATION:
Order No. 823
Final Rule
1. Pursuant to section 215 of the Federal Power Act (FPA), the
Commission approves Reliability Standard PRC-026-1 (Relay Performance
During Stable Power Swings).\1\ The North American Electric Reliability
Corporation (NERC), the Commission-certified Electric Reliability
Organization (ERO), developed and submitted Reliability Standard PRC-
026-1 for Commission approval. Reliability Standard PRC-026-1 applies
to planning coordinators and to generator owners and transmission
owners that apply certain load-responsive protective relays in
specific, identified circumstances. Reliability Standard PRC-026-1 is
designed to ensure the use of protective relay systems that can
differentiate between faults and stable power swings.
---------------------------------------------------------------------------
\1\ 16 U.S.C. 824o.
---------------------------------------------------------------------------
2. The Commission determines that Reliability Standard PRC-026-1
satisfies the directive in Order No. 733 concerning undesirable relay
operation due to power swings.\2\ The Commission concludes that
Reliability Standard PRC-026-1 provides an equally effective and
efficient alternative to the Order No. 733 directive requiring the use
of protective relay systems that can differentiate between faults and
stable power swings and, when necessary, retirement of protective relay
systems that cannot meet this requirement.\3\
---------------------------------------------------------------------------
\2\ Transmission Relay Loadability Reliability Standard, Order
No. 733, 130 FERC ] 61,221, at P 153 (2010), order on reh'g and
clarification, Order No. 733-A, 134 FERC ] 61,127, order on reh'g
and clarification, Order No. 733-B, 136 FERC ] 61,185 (2011).
\3\ Id. P 150.
---------------------------------------------------------------------------
3. The Commission approves NERC's assigned violation risk factors,
violation
[[Page 15636]]
severity levels and implementation plan.
I. Background
A. Mandatory Reliability Standards and Order No. 733 Directives
4. Section 215 of the FPA requires a Commission-certified ERO to
develop mandatory and enforceable Reliability Standards, subject to
Commission review and approval.\4\ Pursuant to section 215 of the FPA,
the Commission established a process to select and certify an ERO,\5\
and subsequently certified NERC.\6\
---------------------------------------------------------------------------
\4\ 16 U.S.C. 824(d) and (e).
\5\ Rules Concerning Certification of the Electric Reliability
Organization; and Procedures for the Establishment, Approval, and
Enforcement of Electric Reliability Standards, Order No. 672, FERC
Stats. & Regs. ] 31,204, order on reh'g, Order No. 672-A, FERC
Stats. & Regs. ] 31,212 (2006).
\6\ North American Electric Reliability Corp., 116 FERC ]
61,062, order on reh'g and compliance, 117 FERC ] 61,126 (2006),
aff'd sub nom. Alcoa, Inc. v. FERC, 564 F.3d 1342 (D.C. Cir. 2009).
---------------------------------------------------------------------------
5. On March 18, 2010, the Commission approved Reliability Standard
PRC-023-1 (Transmission Relay Loadability) in Order No. 733. The
Commission also directed NERC to develop a new Reliability Standard
that required the use of protective relay systems that can
differentiate between faults and stable power swings and, when
necessary, the retirement of protective relay systems that cannot meet
this requirement.\7\ In Order No. 733, the Commission cited the
findings of both NERC and the U.S.-Canada Power System Outage Task
Force on the causes of the 2003 Northeast Blackout, explaining that the
cascade during this event was accelerated by zone 2 and zone 3 relays
that tripped facilities out of service because these devices could not
distinguish between a dynamic, but stable, power swing and an actual
fault.\8\ While the Commission recognized that addressing stable power
swings is a complex issue, Order No. 733 observed that there was no
Reliability Standard to address relays tripping for stable power swings
despite their contribution to the 2003 Northeast Blackout. Accordingly,
the Commission directed NERC to develop a Reliability Standard to
address undesirable relay operation due to stable power swings.\9\
---------------------------------------------------------------------------
\7\ Order No. 733, 130 FERC ] 61,221 at P 150.
\8\ Id. PP 3-4, 130 (citing U.S.-Canada Power System Outage Task
Force, Final Report on the August 14, 2003 Blackout in the United
States and Canada: Causes and Recommendations, at 80 (2004); and
August 14, 2003 Blackout: NERC Actions to Prevent and Mitigate the
Impacts of Future Cascading Blackouts, at 13 (2004)).
\9\ Id. P 153.
---------------------------------------------------------------------------
6. On February 17, 2011, the Commission denied rehearing in Order
No. 733-A, stating that ``[w]e continue to believe that not addressing
stable power swings constitutes a gap in the current Reliability
Standards and must be addressed.'' \10\ Accordingly, the Commission
affirmed the directive in Order No. 733 that NERC develop a Reliability
Standard addressing stable power swings.\11\ The Commission clarified
that it did not require a Reliability Standard containing an absolute
obligation to prevent protection relays from operating unnecessarily
during stable power swings or an across-the-board elimination of all
zone 3 relays; the Commission only required the development of a
Reliability Standard that addresses protection systems that are
vulnerable to stable power swings (resulting from Category B and
Category C contingencies from the NERC Planning Standards in place at
that time) that result in inappropriate tripping.\12\ In Order No. 733-
B, the Commission denied further clarification on this issue.
---------------------------------------------------------------------------
\10\ Order No. 733-A, 134 FERC ] 61,127 at P 104.
\11\ Id.
\12\ Id. P 107.
---------------------------------------------------------------------------
B. NERC Petition and Reliability Standard PRC-026-1
7. On December 31, 2014, NERC submitted a petition seeking approval
of Reliability Standard PRC-026-1, as well as the associated violation
risk factors, violation severity levels and implementation plan.\13\
NERC avers that Reliability Standard PRC-026-1 satisfies the Order No.
733 directive to develop a new Reliability Standard that requires the
use of protective relay systems that can differentiate between faults
and stable power swings. According to NERC, Reliability Standard PRC-
026-1 sets forth requirements that prevent the unnecessary tripping of
bulk electric system elements in response to stable power swings.\14\
NERC further explains that the identification of bulk electric system
elements with protection systems at-risk of operating as a result of a
stable or unstable power swing and the subsequent review by the
applicable generator owner or transmission owner ``provides assurance
that relays will continue to be secure for stable power swings if any
changes in system impedance occur.''\15\
---------------------------------------------------------------------------
\13\ Reliability Standard PRC-026-1 is available on the
Commission's eLibrary document retrieval system in Docket No. RM15-
8-000 and on the NERC Web site, www.nerc.com.
\14\ See NERC Petition at 4.
\15\ Id.
---------------------------------------------------------------------------
8. According to NERC, Reliability Standard PRC-026-1 is ``directly
responsive'' to the Order No. 733 directive that NERC develop a
Reliability Standard addressing undesirable relay operation due to
stable power swings.\16\ However, NERC explains that the Reliability
Standard PRC-026-1 ``includes an alternative to the Commission's
approach to require `the use of protective relay systems that can
differentiate between faults and stable power swings and, when
necessary, phases out protective relay systems that cannot meet this
requirement.' '' \17\ NERC notes that in Order No. 733-A, the
Commission clarified that it had not intended ``to prohibit NERC from
exercising its technical expertise to develop a solution to an
identified reliability concern that is equally effective and efficient
as the one proposed in Order No. 733.'' \18\ In support of its
alternative solution, NERC states that ``it is generally preferable to
emphasize dependability over security when it is not possible to ensure
both for all possible system conditions.'' \19\ NERC also avers that
``[p]rohibiting use of certain types of relays, such as those
protective relay systems that cannot differentiate between faults and
stable power swings, may have unintended negative outcomes for Bulk-
Power System reliability.'' \20\
---------------------------------------------------------------------------
\16\ Id. at 23 (citing Order No. 733, 130 FERC ] 61,221 at P
153).
\17\ Id. (quoting Order No. 733, 130 FERC ] 61,221 at P 162).
\18\ Id. at 11 (citing Order No. 733-A, 134 FERC ] 61,127 at P
11).
\19\ Id. at 24.
\20\ Id.
---------------------------------------------------------------------------
9. Reliability Standard PRC-026-1 has four requirements and two
attachments. NERC explains that Attachment A ``provides clarity on
which load-responsive protective relay functions are applicable'' under
the standard.\21\ Specifically, Attachment A provides that Reliability
Standard PRC-026-1 applies to:
---------------------------------------------------------------------------
\21\ Id. at 31.
any protective functions which could trip instantaneously or with a
time delay of less than 15 cycles on load current (i.e., ``load-
---------------------------------------------------------------------------
responsive''). . . .
According to NERC, the 15 cycle time delay ``is representative of
an expected power swing having a slow slip rate of 0.67 Hertz (Hz) and
is the average time that a stable power swing with that slip rate would
enter the relay's characteristic, reverse direction, and then exit the
characteristic before the time delay expired.'' \22\ NERC states that
the proposed standard does not apply to ``functions that are either
immune to power swings, block power swings, or prevent non-immune
protection function operation due to supervision of
[[Page 15637]]
the function.'' \23\ Attachment B contains the criteria for the
evaluation of load-responsive protective relays that are within the
scope of Reliability Standard PRC-026-1.\24\
---------------------------------------------------------------------------
\22\ Id. at 30.
\23\ Id. at 31.
\24\ See id. at 35-38.
---------------------------------------------------------------------------
10. Under NERC's proposed implementation plan for Reliability
Standard PRC-026-1, Requirement R1 would become effective 12 months
after Commission approval, and Requirements R2, R3 and R4 become
effective 36 months after Commission approval.
C. Notice of Proposed Rulemaking
11. On September 17, 2015, the Commission issued a Notice of
Proposed Rulemaking (NOPR) proposing to approve Reliability Standard
PRC-026-1 as just, reasonable, not unduly discriminatory or
preferential and in the public interest.\25\ The NOPR stated that
Reliability Standard PRC-026-1 appears to adequately address the
Commission's directive in Order No. 733 by helping to prevent the
unnecessary tripping of bulk electric system elements in response to
stable power swings. The NOPR also proposed to accept NERC's proposed
approach as an equally effective and efficient method to achieve the
reliability goal underlying the Commission's Order No. 733 directive.
---------------------------------------------------------------------------
\25\ Relay Performance During Stable Power Swings Reliability
Standard, Notice of Proposed Rulemaking, 80 FR 57549 (Sept. 24,
2015), 152 FERC ] 61,200 (2015).
---------------------------------------------------------------------------
12. In the NOPR, the Commission also expressed concern that NERC's
exclusion of load responsive relays with a time delay of 15 cycles or
greater, as proposed in Attachment A to Reliability Standard PRC-026-1,
could result in a gap in reliability. The Commission explained that,
pursuant to Attachment A, Reliability Standard PRC-026-1 applies to
``any protective functions which could trip instantaneously or with a
time delay of less than 15 cycles on load current (i.e., ``load-
responsive''). . . .'' The Commission further explained that, although
NERC offered a technical rationale for the less than 15 cycle
threshold, explaining that load-responsive relays set to trip
instantaneously or with a ``slight time delay'' are most susceptible to
power swings, NERC did not supply information on the burden of
including relays with a time delay of 15 cycles or greater under
Reliability Standard PRC-026-1.\26\ The Commission stated that the lack
of this information is significant in light of the fact that an entity
would not be required under Reliability Standard PRC-026-1 to
investigate an element identified by a planning coordinator as
potentially susceptible to power swings or investigate an element
following a known power swing trip if the relay(s) involved have a time
delay of 15 cycles or greater.\27\
---------------------------------------------------------------------------
\26\ See NOPR, 152 FERC ] 61,200 at P 14 (citing NERC Petition
at 29-30).
\27\ Id.
---------------------------------------------------------------------------
13. The NOPR requested comments on the potential burden of
modifying the applicability of Reliability Standard PRC-026-1 to
include relays with a time delay of 15 cycles or greater in instances
where either: (1) An element has been identified by a planning
coordinator as potentially susceptible to power swings; or (2) an
entity becomes aware of a bulk electric system element that tripped in
response to a stable or unstable power swing due to the operation of
its protective relay(s), even if the element was not previously
identified by the planning coordinator. The Commission stated that it
may direct NERC to develop modifications to Reliability Standard PRC-
026-1 depending on the response to the questions on the applicability
of Reliability Standard PRC-026-1.
14. In response to the NOPR, seven entities submitted comments. A
list of commenters appears in Appendix A. The comments have informed
our decision making in this Final Rule.
II. Discussion
15. Pursuant to section 215(d)(2) of the FPA, we approve
Reliability Standard PRC-026-1 as just, reasonable, not unduly
discriminatory or preferential, and in the public interest. We also
approve NERC's proposed violation risk factors, violation severity
levels and implementation plan. While Reliability Standard PRC-026-1
does not prohibit the use of relays that cannot differentiate between
faults and stable power swings, Reliability Standard PRC-026-1
addresses the prevention of unnecessary tripping of bulk electric
system elements in response to stable power swings. Accordingly, we
approve NERC's approach as an equally effective and efficient method to
achieve the reliability goal underlying the Commission's directive in
Order No. 733.
16. As discussed below, based on the NOPR comments, we conclude
that the potential reliability gap identified in the NOPR, resulting
from the exclusion of load responsive relays with a time delay of 15
cycles or greater as proposed in Attachment A to Reliability Standard
PRC-026-1, is adequately addressed by the provisions of Reliability
Standards TPL-001-4 and PRC-004-4.\28\
---------------------------------------------------------------------------
\28\ As of January 1, 2016, all requirements of Reliability
Standard TPL-001-4 are subject to enforcement. Reliability Standard
PRC-004-4 was approved May 29, 2015 and will be subject to
enforcement July 1, 2016.
---------------------------------------------------------------------------
Load Responsive Relays With a Delay of 15 Cycles or Greater
Comments
17. NERC, Luminant, NAGF, Tri-State, Idaho Power and EEI support
the Commission's proposal to approve Reliability Standard PRC-026-1. In
response to the NOPR's question regarding the burden of expanding the
applicability of Reliability Standard PRC-026-1 to include load
responsive relays with a time delay of 15 cycles or greater, NERC and
other commenters offer two responses. First, commenters maintain that
the 15 cycle limitation in Reliability Standard PRC-026-1 does not
result in a reliability gap because of how Reliability Standard PRC-
026-1 interacts with other Reliability Standards to address the
Commission's concern. Second, commenters assert that expanding the
applicability of Reliability Standard PRC-026-1 would result in an
unnecessary, significant burden or risk to reliability.
18. NERC, EEI, Tri-State and Luminant claim that no reliability gap
results from the 15 cycle limitation in Reliability Standard PRC-026-1
because planning assessments required by Reliability Standard TPL-001-4
already address the Commission's concerns regarding relays with a time
delay of 15 cycles or greater in instances where an element has been
identified by a planning coordinator as potentially susceptible to
power swings.\29\ Specifically, NERC explains that a planning
assessment conducted pursuant to Reliability Standard TPL-001-4 ``will
reveal Elements with load-responsive protective relays having time
delays of 15 cycles or greater that trip due to power swings.'' \30\
NERC further contends that, where an element that trips causes a
violation of Reliability Standard TPL-001-4 performance criteria, ``the
Planning Coordinator is required to mitigate these conditions through a
Corrective Action Plan.'' \31\ EEI agrees with NERC's assessment and
identifies Reliability Standard TPL-001-4, Requirement R4, Subpart
4.1.2 and Requirement R2, Subpart 2.7 as the corresponding
requirements.\32\
---------------------------------------------------------------------------
\29\ NERC Comments at 5-6. See also Tri-State Comments at 4;
Luminant Comments at 3.
\30\ NERC Comments at 6.
\31\ Id.
\32\ EEI Comments at 7.
---------------------------------------------------------------------------
[[Page 15638]]
19. In addition, NERC and industry commenters state that
Reliability Standard PRC-004-4 addresses the Commission's concern
regarding situations where a bulk electric system element trips in
response to a stable or unstable power swing due to the operation of
its protective relay(s).\33\ Specifically, NERC explains that tripping
unnecessarily ``due to an actual stable power swing would be classified
as a Misoperation under PRC-004-4 (Protection System Misoperation
Identification and Correction).'' \34\ NERC explains that a ``Generator
Owner and Transmission Owner are required to develop a corrective
action plan to address the cause(s) of the Misoperation, for example,
tripping due to a load-responsive protective relay set with a time
delay of 15 cycles or greater, unless reliability would not be
improved.'' \35\
---------------------------------------------------------------------------
\33\ NERC Comments at 9-10. See also EEI Comments at 8; Tri-
State Comments at 5.
\34\ NERC Comments at 9.
\35\ Id.
---------------------------------------------------------------------------
20. Regarding the potential burden of expanding the applicability
of Reliability Standard PRC-026-1 to cover relays with a time delay of
15 cycles or greater, NERC and industry commenters state that expanding
the applicability of Requirement R1, Criteria 4 (element has been
identified by a planning coordinator) would increase the burden on
transmission owners and generator owners.\36\ NERC states that there
would be no increase in burden for the planning coordinator because the
planning coordinator is required by Reliability Standard TPL-001-4,
Requirement R4 ``to perform contingency analyses based on computer
simulation models for the Stability portion of the annual Planning
Assessment.'' \37\ As noted above, NERC explains that where an element
that trips during the annual planning assessment causes a violation of
Reliability Standard TPL-001-4 performance criteria, ``the Planning
Coordinator is required to mitigate these conditions through a
Corrective Action Plan.'' \38\
---------------------------------------------------------------------------
\36\ See id. at 7, 9. See also EEI Comments at 6; Luminant
Comments at 4; Idaho Power Comments at 2.
\37\ NERC Comments at 5.
\38\ Id.
---------------------------------------------------------------------------
21. NERC, however, states that expanding the applicability of
Reliability Standard PRC-026-1 to cover relays with a time delay of 15
cycles or greater would ``place additional burden on the Generator
Owner and Transmission Owner for any Elements that are identified using
Requirement R1, Criteria 4.'' \39\ NERC explains that the additional
burden ``would be determined by the increase in the quantity of load-
responsive protective relays applied to that Element beyond what is
proposed in PRC-026-1 (i.e. load-responsive protective relays with time
delays of 15 cycles or greater).'' NERC continues that the ``increase
in burden could be on the order of two to three times in magnitude to
address zone 2 (not communication-aided) and application of reverse
zone and/or forward zone 4 remote back-up time delayed elements.'' \40\
---------------------------------------------------------------------------
\39\ Id. at 6.
\40\ Id. at 7.
---------------------------------------------------------------------------
22. EEI contends that the additional burden would ``vary greatly by
entity size and asset configuration, however, the work associated with
this effort would not be inconsequential and would consume significant
dollars for large entities while tying up critical and often scarce
engineering resources across the industry.'' \41\ EEI explains that
even though the Commission proposes to limit the analysis to the two
scenarios identified in the NOPR, the proposal would increase the
number of relay elements evaluated by 100 to 200 percent at impacted
transmission lines, generators and transformer terminals.\42\
---------------------------------------------------------------------------
\41\ EEI Comments at 6.
\42\ Id.
---------------------------------------------------------------------------
23. ITC, while not taking a position on the merits of the
particular requirements of Reliability Standard PRC-026-1, argues
``that studies and information now available concerning relay
performance during stable power swings controvert the Commission's at-
the-time reasonable determination in Order No. 733 that a Standard to
address relay performance during stable power swings was warranted.''
\43\ In particular, ITC ``urge[s] the Commission to consider the [NERC
System Protection and Control Subcommittee] Report findings in issuing
its final rule in this proceeding.'' \44\ ITC asserts that the SPSC
Report undercuts the rationale for promulgating Reliability Standard
PRC-026-1 and argues that ``the Commission should reconsider the
necessity of PRC-026-1, particularly in light of the burden NERC has
determined the new Standard would impose.'' \45\
---------------------------------------------------------------------------
\43\ ITC Comments at 3.
\44\ Id. (referencing NERC System Protection and Control
Subcommittee, ``Protection System Response to Power Swings'' (2013)
(SPSC Report)).
\45\ Id. at 4.
---------------------------------------------------------------------------
Commission Determination
24. We find that Reliability Standard PRC-026-1 addresses the
Commission's directive in Order No. 733 by providing measures to
mitigate the unnecessary tripping of bulk electric system elements in
response to stable power swings. While it does not prohibit the use of
relays that cannot differentiate between faults and stable power
swings, we conclude that Reliability Standard PRC-026-1's approach is
an equally effective and efficient method to achieve the reliability
goal underlying the Commission's directive in Order No. 733.
25. While ITC asks that the Commission reconsider the necessity of
PRC-026-1 in light of the SPSC Report, the Commission continues to
believe in the necessity of a Reliability Standard that addresses the
performance of relays during stable power swings. In response to ITC's
comments, the recommendations from the 2013 SPSC Report were used in
the development of Reliability Standard PRC-026-1. As noted by NERC,
Reliability Standard PRC-026-1 ``is based on and is consistent with the
recommendations found in the [SPSC] Report.'' \46\ Accordingly, we
conclude that Reliability Standard PRC-026-1 reflects the
recommendations outlined in the SPSC Report.
---------------------------------------------------------------------------
\46\ NERC Petition at 15-16.
---------------------------------------------------------------------------
26. Based on the NOPR comments, we are persuaded that the potential
reliability gap identified in the NOPR, resulting from the exclusion of
load responsive relays with a time delay of 15 cycles or greater as
proposed in Attachment A to Reliability Standard PRC-026-1, is
adequately addressed by requirements of Reliability Standards TPL-001-4
(Transmission System Planning Performance Standards) and PRC-004-4
(Protection System Misoperation Identification and Correction). We
agree with commenters that these Reliability Standards adequately
address the risk posed by load responsive relays with a time delay of
15 cycles or greater in the two cases identified in the NOPR.
Accordingly, we do not direct any modifications to Reliability Standard
PRC-026-1 at this time.
27. First, where an element has been identified by a planning
coordinator as potentially susceptible to power swings, Reliability
Standard TPL-001-4 addresses the NOPR's concern by requiring applicable
entities to both (1) identify elements with load-responsive protective
relays having time delays of 15 cycles or greater that trip due to
power swings and (2) mitigate through a corrective action plan where
Reliability Standard TPL-001-4 performance criteria are not met.
Specifically, Reliability Standard TPL-001-4 sets forth the parameters
for
[[Page 15639]]
certain studies associated with the annual planning assessment that are
intended to identify, among other things, situations where a
transmission system element trips due to an impedance swing resulting
from a generator pulling out of synchronization.\47\ An element that
trips due to the criteria in Requirement R4, Subpart 4.1.2 fails to
meet the performance requirements in Table 1 of Reliability Standard
TPL-001-4. When an element fails to meet the performance requirements
in Table 1, the planning coordinator is required to develop a
``Corrective Action Plan(s) addressing how the performance requirements
will be met.'' \48\ Therefore, Reliability Standard TPL-001-4 addresses
the concerns raised in the NOPR regarding the exclusion of load
responsive relays with a time delay of 15 cycles or greater from
Requirement R1 of Reliability Standard PRC-026-1.
---------------------------------------------------------------------------
\47\ See Reliability Standard TPL-001-4 (Transmission System
Planning Performance Requirements), Requirement R4, Subpart 4.1.2.
\48\ Id., Requirement R2, Subpart 2.7.
---------------------------------------------------------------------------
28. Second, where an entity becomes aware of a bulk electric system
element that tripped in response to a stable or unstable power swing
due to the operation of its protective relay(s), we agree with
commenters that the tripping would be classified as a misoperation
under Reliability Standard PRC-004-4.\49\ Therefore, the generator
owner or transmission owner would be required to develop a corrective
action plan to address the cause(s) of the misoperation, which in this
case would be tripping due to a load-responsive protective relay set
with a time delay of 15 cycles or greater, unless the transmission
owner or generation owner ``explains in a declaration why corrective
action plans are beyond the entity's control or would not improve BES
reliability.'' \50\ Specifically, Reliability Standard PRC-004-4
requires entities to investigate and mitigate, through a corrective
action plan, any misoperation.\51\ A misoperation under Reliability
Standard PRC-004-4 includes, in pertinent part, unnecessary trips for
non-fault conditions resulting from power swings.\52\ Therefore,
Reliability Standard PRC-004-4 addresses the concerns raised in the
NOPR regarding the exclusion of load responsive relays with a time
delay of 15 cycles or greater from Requirement R2, Part 2.2 of
Reliability Standard PRC-026-1.
---------------------------------------------------------------------------
\49\ See, e.g., NERC Comments at 9-10, EEI Comments at 8.
\50\ Reliability Standard PRC-004-4 (Protection System
Misoperation and Correction), Requirement R5.
\51\ See id.
\52\ Id., Application Guidelines at 22.
---------------------------------------------------------------------------
29. Finally, concerns with the potential burden of expanding the
applicability of Reliability Standard PRC-026-1 to cover relays with a
time delay of 15 cycles or greater in order to address the potential
reliability gap identified in the NOPR are moot given our determination
above that the potential reliability gap identified in the NOPR is
adequately addressed by existing Reliability Standard requirements.
III. Information Collection Statement
30. The FERC-725G \53\ information collection requirements
contained in this Final Rule are subject to review by the Office of
Management and Budget (OMB) regulations under section 3507(d) of the
Paperwork Reduction Act of 1995 (PRA).\54\ OMB's regulations require
approval of certain informational collection requirements imposed by
agency rules.\55\ 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 a rule will not be penalized for
failing to respond to these collections of information unless the
collections of information display a valid OMB control number.
---------------------------------------------------------------------------
\53\ The requirements in the RM15-8-000 NOPR were submitted to
OMB within FERC-725G3 (OMB Control Number 1902-0285). FERC-725G3 is
a temporary collection that enabled timely submission to OMB. The
requirements are now being submitted to the information collection
intended for these requirements, specifically FERC-725G (OMB Control
No. 1902-0252).
\54\ 44 U.S.C. 3507(d).
\55\ 5 CFR 1320.11.
---------------------------------------------------------------------------
31. The Commission solicited comments on the need for this
information, whether the information will have practical utility, the
accuracy of the burden estimates, ways to enhance the quality, utility,
and clarity of the information to be collected or retained, and any
suggested methods for minimizing respondents' burden, including the use
of automated information techniques. Specifically, the Commission asked
that any revised burden or cost estimates submitted by commenters be
supported by sufficient detail to understand how the estimates are
generated. The Commission did not receive any comments on the estimates
in the NOPR.
Public Reporting Burden: The Commission approves Reliability
Standard PRC-026-1. Reliability Standard PRC-026-1 will impose new
requirements for the notification of particular bulk electric system
elements from planning coordinator to generator owners and
transmissions owners based on given criteria. Generator owners and
transmissions owner will evaluate those bulk electric system elements
and load-responsive protective relay(s) according to Attachment B
criteria and, if a load-responsive protective relay does not meet the
Attachment B criteria, the generator owner/transmission owner must
develop a corrective action plan. Our estimate below regarding the
number of respondents is based on the NERC Compliance Registry as of
June 26, 2015. According to the NERC Compliance Registry, NERC has
registered 318 transmission owners, 884 generator owners, and 68
planning coordinators. However, under NERC's compliance registration
program, entities may be registered for multiple functions, so these
numbers incorporate some double counting. The total number of unique
entities that may be identified as a notification provider (e.g.
applicable entity) in accordance with proposed Reliability Standard
PRC-026-1 will be approximately 1,074 entities registered in the United
States as a transmission owner and/or generator owner. The total number
of unique entities that may be identified as evidence retention
entities (e.g. applicable entity) in accordance with proposed
Reliability Standard PRC-026-1 will be approximately 1,092 entities
registered in the United States as a transmission owner, generator
owner and/or planning coordinator. The Commission estimates the annual
reporting burden and cost as follows:
[[Page 15640]]
RM15-8-000 (Mandatory Reliability Standards--Reliability Standard PRC-026-1)
--------------------------------------------------------------------------------------------------------------------------------------------------------
Total annual
Number of Annual number Total number Average burden burden hours & Cost per
respondents of responses of responses & cost per total annual respondent ($)
per respondent response cost
(1) (2) (1) * (2) = (4) (3) * (4) = (5) / (1)
(3) (5)
--------------------------------------------------------------------------------------------------------------------------------------------------------
Notifications to GO/TO per Requirement R1............... 1,074 1 1,074 8, $485.28 8,592 $485.28
\56\ $521,191
Evidence Retention GO/TO/PC............................. 1,092 1 1,092 12, $450.00 13,104 450.00
\57\ $491,400
-----------------------------------------------------------------------------------------------
Total............................................... .............. .............. 2,166 .............. 21,696 ..............
$1,012,591
--------------------------------------------------------------------------------------------------------------------------------------------------------
Title: FERC-725G, Mandatory Reliability Standards: Reliability
Standard PRC-026-1.
---------------------------------------------------------------------------
\56\ The estimates for cost per response are derived using the
following formula:
Average Burden Hours per Response * $60.66 per Hour = Average
Cost per Response. The hourly average of $60.66 assumes equal time
is spent by the manager, electrical engineer, and information and
record clerk. The average hourly cost (salary plus benefits) is:
$37.50 for information and record clerks (occupation code 43-4199),
$78.04 for a manager (occupation code 11-0000), and $66.45 for an
electrical engineer (occupation code 17-2071). (The figures are
taken from the Bureau of Labor Statistics, May 2014 figures at
https://www.bls.gov/oes/current/naics2_22.htm.)
\57\ The average hourly cost (salary plus benefits) is $37.50.
The BLS wage category code is 34-4199. This figure is also taken
from the Bureau of Labor Statistics, May 2014 figures at https://www.bls.gov/oes/current/naics2_22.htm.
---------------------------------------------------------------------------
Action: Collection of Information.
OMB Control No: 1902-0252.
Respondents: Business or other for-profit and not-for-profit
institutions.
Frequency of Responses: One time and on-going.
Necessity of the Information: Reliability Standard PRC-026-1 will
implement the Congressional mandate of the Energy Policy Act of 2005 to
develop mandatory and enforceable Reliability Standards to better
ensure the reliability of the nation's Bulk-Power System. Specifically,
the Reliability Standard will address undesirable relay operation due
to power swings.
32. Internal review: The Commission has reviewed the requirements
pertaining to the Reliability Standard PRC-026-1 and made a
determination that the requirements of this standard are necessary to
implement section 215 of the FPA. These requirements conform to the
Commission's plan for efficient information collection, communication
and management within the energy industry. The Commission has assured
itself, by means of its internal review, that there is specific,
objective support for the burden estimates associated with the
information requirements.
33. Interested persons may obtain information on the reporting
requirements by contacting the Federal Energy Regulatory Commission,
Office of the Executive Director, 888 First Street, NE., Washington, DC
20426 [Attention: Ellen Brown, email: DataClearance@ferc.gov, phone:
(202) 502-8663, fax: (202) 273-0873].
34. Comments concerning the information collections approved in
this Final Rule and the associated burden estimates, should be sent to
the Commission in this docket and may also be sent to the Office of
Management and Budget, Office of Information and Regulatory Affairs
[Attention: Desk Officer for the Federal Energy Regulatory Commission,
phone: (202) 395-0710, fax: (202) 395-7285]. For security reasons,
comments should be sent by email to OMB at the following email address:
oira_submission@omb.eop.gov. Please reference the docket number of this
Final Rule (Docket No. RM15-8-000) in your submission.
IV. Regulatory Flexibility Act Analysis
35. The Regulatory Flexibility Act of 1980 (RFA) \58\ generally
requires a description and analysis of this Final Rule that will have
significant economic impact on a substantial number of small entities.
Reliability Standard PRC-026-1 sets forth requirements that prevent the
unnecessary tripping of bulk electric system elements in response to
stable power swings. As shown in the information collection section, an
estimated 1,092 entities are expected to evaluate bulk electric system
elements and load-responsive protective relay(s) according to
Attachment B criteria of PRC-026-1. Comparison of the applicable
entities with the Commission's small business data indicates that
approximately 661 are small entities \59\ or 60.53 percent of the
respondents affected by Reliability Standard PRC-026-1.
---------------------------------------------------------------------------
\58\ 5 U.S.C. 601-612.
\59\ The Small Business Administration sets the threshold for
what constitutes a small business. Public utilities may fall under
one of several different categories, each with a size threshold
based on the company's number of employees, including affiliates,
the parent company, and subsidiaries. For the analysis in this rule,
we apply a 500 employee threshold for each affected entity. Each
entity is classified as Electric Bulk Power Transmission and Control
(NAICS code 221121).
---------------------------------------------------------------------------
36. As discussed above, Reliability Standard PRC-026-1 will serve
to enhance reliability by imposing mandatory requirements governing
generator relay loadability, thereby reducing the likelihood of
premature or unnecessary tripping of generators during system
disturbances. The Commission estimates that each of the small entities
to whom the Reliability Standard PRC-026-1 applies will incur paperwork
and record retention costs of $935.28 per entity (annual ongoing).
37. The Commission does not consider the estimated costs per small
entity to have a significant economic impact on a substantial number of
small entities. Accordingly, the Commission certifies that Reliability
Standard PRC-026-1 will not have a significant economic impact on a
substantial number of small entities. Accordingly, no regulatory
flexibility analysis is required.
V. Environmental Analysis
38. 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.\60\ 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,
[[Page 15641]]
or procedural or that do not substantially change the effect of the
regulations being amended.\61\ The actions herein fall within this
categorical exclusion in the Commission's regulations.
---------------------------------------------------------------------------
\60\ Regulations Implementing the National Environmental Policy
Act of 1969, Order No. 486, FERC Stats. & Regs. ] 30,783 (1987).
\61\ 18 CFR 380.4(a)(2)(ii) (2015).
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VI. Effective Date and Congressional Notification
39. This Final Rule is effective May 23, 2016. The Commission has
determined, with the concurrence of the Administrator of the Office of
Information and Regulatory Affairs of OMB, that this rule is not a
``major rule'' as defined in section 351 of the Small Business
Regulatory Enforcement Fairness Act of 1996. This Final Rule is being
submitted to the Senate, House, and Government Accountability Office.
VII. Document Availability
40. 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 the Commission's Home Page (https://www.ferc.gov) and
in the Commission's Public Reference Room during normal business hours
(8:30 a.m. to 5:00 p.m. Eastern time) at 888 First Street NE., Room 2A,
Washington, DC 20426.
41. From the Commission'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 of this document, excluding the last three digits, in
the docket number field.
42. User assistance is available for eLibrary and the Commission's
Web site during normal business hours from the Commission's Online
Support at 202-502-6652 (toll free at 1-866-208-3676) or email at
ferconlinesupport@ferc.gov, or the Public Reference Room at (202) 502-
8371, TTY (202) 502-8659. Email the Public Reference Room at
public.referenceroom@ferc.gov.
By the Commission.
Issued: March 17, 2016.
Nathaniel J. Davis, Sr.,
Deputy Secretary.
Note: The following Appendix will not appear in the Code of
Federal Regulations.
Appendix
Commenters
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Abbreviation Commenter
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EEI.................................. Edison Electric Institute.
Idaho Power.......................... Idaho Power Company.
ITC.................................. International Transmission
Company.
Luminant............................. Luminant Generation Company LLC.
NERC................................. North American Electric
Reliability Corporation.
NAGF................................. North American Generator Forum.
Tri-State............................ Tri-State Generation and
Transmission Association, Inc.
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[FR Doc. 2016-06508 Filed 3-23-16; 8:45 am]
BILLING CODE 6717-01-P
