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{{#Wiki_filter:}} | {{#Wiki_filter:NERC NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION | ||
* High Reliability in 2018, No Non-Weather Category 3, 4, or 5 events | |||
* Hurricane Michael and Florence Category 3 | |||
* Extreme weather events continue to be leading contributor to the largest generation and distribution outages | |||
* Better than expected performance from Texas generation fleet helped meet 2018 summer peak demand; reliability risk in 2019 due to continued capacity deficit | |||
* Continued downward misoperation rate trend | |||
* Improving or stable frequency response performance in all interconnections | |||
* Emerging reliability challenges identified as more inverter-based generation is added 2 RELIABILITY I ACCOUNTABILITY | |||
2018 Actual Energy 99.92°/o Time with no epe1ator,-c:011bolled The ERO Enterpri~ : NERC and 7 Regional Entities 1,028,629 MW load shedding 2018 Sc.mmer Pea~ Capacity t!!ES......rn~ ~ - | |||
* 469,842 mi Total Transmission Circuit MIies > 100W 0 TEXAS RE ~ WECC Category 3, 4. or 5 Events (non-weather1'81ated) 15 Reliability Coordinators 4 Interconnections 5,816 Number of Conuentlonal C..181atlng Units >20MW 184 Transmission Operators 991 Generator Owners 73 Balancing Authorities 398 Distribution Providers Bui~ Power System Situation Awareness Inputs and Products in 2018 --- | |||
: Ill v' - | |||
v' - | |||
x- .. | |||
v' - | |||
3 ( | |||
200 180 Category 1 160 140 | |||
~ | |||
C (I) | |||
> 120 LU 0 100 ai | |||
.0 80 E | |||
Category 2 z 60 40 20 0 | |||
2014 2015 2016 2017 2018 | |||
* Category 1 | |||
* Category 2 Category 3 | |||
* Category 4 | |||
* Category 5 Category 3 | |||
* Design/Engineering | |||
* Management/Organization | |||
* Equipment/Material Category 4 | |||
* Training | |||
* Other | |||
* Individual Performance | |||
* Communication Category s 4 RELIABILITY I ACCOUNTABILITY | |||
2014-2018 Event Analysis Trends | |||
* Management/ Organizat ion | |||
* Design/ Engineering 856 Event Reports | |||
* Equipment/Material | |||
* Other | |||
* Communication | |||
* Individual Perfo rmance 378 Identified Root Causes | |||
* Tra ining | |||
* No Causes Found | |||
* Overall Configuration 1% | |||
116 MW 2014-2018 Identified Root Causes Overall (Five-Year) Average Load Loss of (Processed to-date) | |||
Non-Weather Driven Events with Load Loss Number of N on-Weather Events with Tota l Category 1 Events by Year and Load Loss and Annual Average Load Loss Subcategory 40 300 200 | |||
'i: | |||
34 ~ 180 250 ~ | |||
Q) | |||
LU | |||
> 160 | |||
* lh | |||
~ 30 :: | |||
Q) | |||
Q) a la | |||
..c 200 LLI 140 iii a le Q) | |||
~ | |||
ai 120 lb | |||
~0 20 150 "'"'0 100 | |||
* lf | |||
...J z -0 Cll 80 a 1g | |||
'o 100 0 | |||
...J | |||
~ | |||
60 a 1d | |||
_2,; 10 Q) | |||
E so OJ) | |||
~ | |||
a le | |||
::, Q) 40 z > | |||
<l'. | |||
20 0 0 2014 2015 2016 2017 2018 0 2014 2015 2016 2017 2018 | |||
- Total ~ Annual Average Load Loss (MW) s | |||
6 RELIABILITY I ACCOUNTABILITY NERC Reliability Indicator - Transmission NORTH AMERICAN ELECTRIC RELIAGILITY CORPORATION Related Events Results in Loss of Load 20 350 -0 300 .., | |||
Q) a. | |||
~ 15 ::J C: | |||
Q) 250 ~ | |||
Q) | |||
UJ 200 .= E | |||
~ | |||
0.., 10 -0 *- | |||
C: u. | |||
150 ro - | |||
C: | |||
::J ES 0 5 100 Q) ~ | |||
u Cl - | |||
so Q) | |||
Q.() | |||
ro | |||
~ | |||
0 0 Q) 2014 2015 2016 2017 2018 ~ | |||
- Count of Events -e- Average of Demand Interrupted (MW) Firm 7 RELIABILITY I ACCOUNTABILITY | |||
NERC Reliability Indicator - Protection System NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION M*isoperat*ion Rate 14% 13.29% | |||
12.0% | |||
12% | |||
10.0% | |||
10% | |||
8.0% | |||
8% | |||
6.0% | |||
6% | |||
4.0% | |||
4% | |||
2.0% | |||
2% | |||
0.0% | |||
Q4 2013 - Q3 Q4 2014 - Q3 Q4 2015 - Q3 Q4 2016 - Q3 Q4 2017 - Q3 2014 2015 2016 2017 2018 0% | |||
FRCC MRO NPCC RF SERC Texas RE WECC Annual Protection System Five-Year Protection System Misoperation Rate Misoperation Rate by Region Q4 2013 through Q3 2018 8 RELIABILITY I ACCOUNTABILITY | |||
Tranmission Loss 30% | |||
Load Loss 60% | |||
Generation Loss 10% | |||
9 RELIABILITY I ACCOUNTABILITY | |||
100 | |||
. Ten Highest Stress Days with 2018 marked | |||
~/2 Winter Storm | |||
: 9/.14 Hurricane Florence 11/15 Winter Storm I | |||
10 116 5 II) | |||
* 1/2 Severe Cold Weather | |||
*xtU | |||
~ | |||
...I a: | |||
V, 1 | |||
- 2012 - 2014 - 2015 - 2016 2017 -2018 0.1 Descending day of the year 10 RELIABILITY I ACCOUNTABILITY | |||
NERC Severity Risk Index (SRI) - | |||
NORTH AMERICAN ELECTRIC RELIAB I LITY CORPORAT I ON Cumulative 750 2012 700 650 600 550 500 VI c.. | |||
450 | |||
..0 ex:: | |||
400 V1 Q) 350 | |||
-~ | |||
+"' 300 ro 250 E | |||
u 200 150 100 so 0 | |||
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec | |||
- 2012 - 2014 - 2015 - 2016 - 2017 2018 11 RELIABILITY I ACCOUNTABILITY | |||
NERC BPS Planning and Adapting to a NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION Changing Resource Mix NERCAlert 1 | |||
* Concerns with Susceptible to Erroneous Inverter cease output during i nve rte r-ba sed Frequency Calculations? abnormal voltages? | |||
resource persist and mitigation strategies | |||
* Yti a No a YES | |||
* 'o are being developed by the NERC Inverter-Based Resources Task Force. NERC Alert II | |||
* NERC Alert helped Use Momentary 1.8GW Cannot be fully mitigated inform industry of the Total BPS Solar Cessation Can be mitigated vu Inera bi lities through settings change associated with I Can be fully momentary cessation. 3.9 GW 5.2 GW mitigated Dontt Use Momentary Cessation 12 RELIABILITY I ACCOUNTABILITY | |||
1 - Continue improving their ability to understand, model, and plan for a system with a significantly different resource mix. Priority should be given to: | |||
Frequency response under low inertia conditions Contributions of inverter-based resources to essential reliability services 11 Increasing protection system and restoration complexities with increased inverter-based resources Resource adequacy with increasing energy constraints 2 - Develop comparative metrics to understand the different dimensions of resilience during extreme events and system performance changes over time. | |||
3 - Better understand and share information on cyber and physical security threats and mitigate the risks through a variety of approaches, including resilient system design, consequence-informed planning and operation, and practicing response and recovery processes. | |||
13 RELIABILITY I ACCOUNTABILITY | |||
NERC NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION | |||
* May 2019: NERC launched a Task Force to identify reliability concerns associated with EMPs and potential methods for promoting resilience | |||
* The Task Force advises NERC, regulators, Regional Entities, and industry stakeholders to establish a common understanding of the scope, priority, and goals for the development of next-steps to address resilience to HEMP events 15 RELIABILITY I ACCOUNTABILITY | |||
Strategic Recommendations Technical Committee Work Standard Drafting Team (if applicable) | |||
Phase 3 16 RELIABILITY I ACCOUNTABILITY | |||
* The Task Force has broken up the topic of EMP as it relates to the utility industry in the following categories: | |||
* Policy- What needs to be clearly defined by industry and federal government | |||
* Research - What research is needed to prudently inform utilities that need to make decisions | |||
* Vulnerability Assessments - How does the utility industry take the policy and research to understand its vulnerability | |||
* Mitigation Guidelines - Fundamental suggestions and guidelines on prudent mitigation strategies | |||
* Response and Recovery- Based on the vulnerability assessments and any mitigation guidelines, for any impacted facilities, how does a utility respond and recover 17 RELIABILITY I ACCOUNTABILITY | |||
wers 18 RELIABILITY I ACCOUNTABILITY}} |
Latest revision as of 19:47, 1 February 2020
ML19270D575 | |
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Issue date: | 09/25/2019 |
From: | NRC/OCM |
To: | |
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ML19270D537 | List: |
References | |
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Download: ML19270D575 (18) | |
Text
NERC NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION
- High Reliability in 2018, No Non-Weather Category 3, 4, or 5 events
- Hurricane Michael and Florence Category 3
- Extreme weather events continue to be leading contributor to the largest generation and distribution outages
- Better than expected performance from Texas generation fleet helped meet 2018 summer peak demand; reliability risk in 2019 due to continued capacity deficit
- Continued downward misoperation rate trend
- Improving or stable frequency response performance in all interconnections
- Emerging reliability challenges identified as more inverter-based generation is added 2 RELIABILITY I ACCOUNTABILITY
2018 Actual Energy 99.92°/o Time with no epe1ator,-c:011bolled The ERO Enterpri~ : NERC and 7 Regional Entities 1,028,629 MW load shedding 2018 Sc.mmer Pea~ Capacity t!!ES......rn~ ~ -
- 469,842 mi Total Transmission Circuit MIies > 100W 0 TEXAS RE ~ WECC Category 3, 4. or 5 Events (non-weather1'81ated) 15 Reliability Coordinators 4 Interconnections 5,816 Number of Conuentlonal C..181atlng Units >20MW 184 Transmission Operators 991 Generator Owners 73 Balancing Authorities 398 Distribution Providers Bui~ Power System Situation Awareness Inputs and Products in 2018 ---
- Ill v' -
v' -
x- ..
v' -
3 (
200 180 Category 1 160 140
~
C (I)
> 120 LU 0 100 ai
.0 80 E
Category 2 z 60 40 20 0
2014 2015 2016 2017 2018
- Category 1
- Category 2 Category 3
- Category 4
- Category 5 Category 3
- Design/Engineering
- Management/Organization
- Equipment/Material Category 4
- Training
- Other
- Individual Performance
- Communication Category s 4 RELIABILITY I ACCOUNTABILITY
2014-2018 Event Analysis Trends
- Management/ Organizat ion
- Design/ Engineering 856 Event Reports
- Equipment/Material
- Other
- Communication
- Individual Perfo rmance 378 Identified Root Causes
- Tra ining
- No Causes Found
- Overall Configuration 1%
116 MW 2014-2018 Identified Root Causes Overall (Five-Year) Average Load Loss of (Processed to-date)
Non-Weather Driven Events with Load Loss Number of N on-Weather Events with Tota l Category 1 Events by Year and Load Loss and Annual Average Load Loss Subcategory 40 300 200
'i:
34 ~ 180 250 ~
Q)
LU
> 160
- lh
~ 30 ::
Q)
Q) a la
..c 200 LLI 140 iii a le Q)
~
ai 120 lb
~0 20 150 "'"'0 100
- lf
...J z -0 Cll 80 a 1g
'o 100 0
...J
~
60 a 1d
_2,; 10 Q)
E so OJ)
~
a le
- , Q) 40 z >
<l'.
20 0 0 2014 2015 2016 2017 2018 0 2014 2015 2016 2017 2018
- Total ~ Annual Average Load Loss (MW) s
6 RELIABILITY I ACCOUNTABILITY NERC Reliability Indicator - Transmission NORTH AMERICAN ELECTRIC RELIAGILITY CORPORATION Related Events Results in Loss of Load 20 350 -0 300 ..,
Q) a.
~ 15 ::J C:
Q) 250 ~
Q)
UJ 200 .= E
~
0.., 10 -0 *-
C: u.
150 ro -
C:
- J ES 0 5 100 Q) ~
u Cl -
so Q)
Q.()
ro
~
0 0 Q) 2014 2015 2016 2017 2018 ~
- Count of Events -e- Average of Demand Interrupted (MW) Firm 7 RELIABILITY I ACCOUNTABILITY
NERC Reliability Indicator - Protection System NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION M*isoperat*ion Rate 14% 13.29%
12.0%
12%
10.0%
10%
8.0%
8%
6.0%
6%
4.0%
4%
2.0%
2%
0.0%
Q4 2013 - Q3 Q4 2014 - Q3 Q4 2015 - Q3 Q4 2016 - Q3 Q4 2017 - Q3 2014 2015 2016 2017 2018 0%
FRCC MRO NPCC RF SERC Texas RE WECC Annual Protection System Five-Year Protection System Misoperation Rate Misoperation Rate by Region Q4 2013 through Q3 2018 8 RELIABILITY I ACCOUNTABILITY
Tranmission Loss 30%
Load Loss 60%
Generation Loss 10%
9 RELIABILITY I ACCOUNTABILITY
100
. Ten Highest Stress Days with 2018 marked
~/2 Winter Storm
- 9/.14 Hurricane Florence 11/15 Winter Storm I
10 116 5 II)
- 1/2 Severe Cold Weather
- xtU
~
...I a:
V, 1
- 2012 - 2014 - 2015 - 2016 2017 -2018 0.1 Descending day of the year 10 RELIABILITY I ACCOUNTABILITY
NERC Severity Risk Index (SRI) -
NORTH AMERICAN ELECTRIC RELIAB I LITY CORPORAT I ON Cumulative 750 2012 700 650 600 550 500 VI c..
450
..0 ex::
400 V1 Q) 350
-~
+"' 300 ro 250 E
u 200 150 100 so 0
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
- 2012 - 2014 - 2015 - 2016 - 2017 2018 11 RELIABILITY I ACCOUNTABILITY
NERC BPS Planning and Adapting to a NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION Changing Resource Mix NERCAlert 1
- Concerns with Susceptible to Erroneous Inverter cease output during i nve rte r-ba sed Frequency Calculations? abnormal voltages?
resource persist and mitigation strategies
- Yti a No a YES
- NERC Alert helped Use Momentary 1.8GW Cannot be fully mitigated inform industry of the Total BPS Solar Cessation Can be mitigated vu Inera bi lities through settings change associated with I Can be fully momentary cessation. 3.9 GW 5.2 GW mitigated Dontt Use Momentary Cessation 12 RELIABILITY I ACCOUNTABILITY
1 - Continue improving their ability to understand, model, and plan for a system with a significantly different resource mix. Priority should be given to:
Frequency response under low inertia conditions Contributions of inverter-based resources to essential reliability services 11 Increasing protection system and restoration complexities with increased inverter-based resources Resource adequacy with increasing energy constraints 2 - Develop comparative metrics to understand the different dimensions of resilience during extreme events and system performance changes over time.
3 - Better understand and share information on cyber and physical security threats and mitigate the risks through a variety of approaches, including resilient system design, consequence-informed planning and operation, and practicing response and recovery processes.
13 RELIABILITY I ACCOUNTABILITY
NERC NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION
- May 2019: NERC launched a Task Force to identify reliability concerns associated with EMPs and potential methods for promoting resilience
- The Task Force advises NERC, regulators, Regional Entities, and industry stakeholders to establish a common understanding of the scope, priority, and goals for the development of next-steps to address resilience to HEMP events 15 RELIABILITY I ACCOUNTABILITY
Strategic Recommendations Technical Committee Work Standard Drafting Team (if applicable)
Phase 3 16 RELIABILITY I ACCOUNTABILITY
- The Task Force has broken up the topic of EMP as it relates to the utility industry in the following categories:
- Policy- What needs to be clearly defined by industry and federal government
- Research - What research is needed to prudently inform utilities that need to make decisions
- Vulnerability Assessments - How does the utility industry take the policy and research to understand its vulnerability
- Mitigation Guidelines - Fundamental suggestions and guidelines on prudent mitigation strategies
- Response and Recovery- Based on the vulnerability assessments and any mitigation guidelines, for any impacted facilities, how does a utility respond and recover 17 RELIABILITY I ACCOUNTABILITY
wers 18 RELIABILITY I ACCOUNTABILITY