70
October 29, 2018 2018-19 Winter Readiness Workshop 1
October 29, 2018
2018-19 Winter Readiness Workshop
1
2
Agenda
1. Introduction/Opening Remarks R. Benbow
2. Preparedness
a. Winter 2017-18 Lessons Learned R. Benbow
b. Offer Cap Status C. Hansen
c. Winter Resource Assessments
i. Generation (Resource Assessment) E. Rodriguez
ii. Transmission (CSA) B. Relucio
3. Readiness
a. Preparation T. Hines
b. Winterization C. Drake
i. ERCOT Weatherization Review A. Allgower, ERCOT
4. General Discussion/Questions
Winter 2017-18 lessons learned will allow for more efficient management of obligations throughout the year.
3
New Capacity Advisory communication to increase situational awareness and encouraged stakeholders to update market data
Improve collaboration, communication, and coordination within MISO, with members and with neighbors
Provide greater awareness and communication surrounding the Regional Dispatch Transfer constraint
Internal training and drills on Emergency Purchases
Proactively engage with Generator and Transmission Owners to identify outages flexible to address any tight operating conditions
Clarified roles around public appeal requests
4
MISO continues to promote cost-effective and innovative solutions to increase preparedness and respond to challenging situations
Continued improvements on
Emergency Pricing
Conduct drills and training on Emergency
Purchases with external entities
Improve management of
uncertainty between DA and RT load
forecasts
Continue to work with Joint Parties on
management of the Regional Dispatch
Transfer
Coordinate with RAN* effort to address
demand side management and
emergency procedures
*Resource Availability and Need (RAN)
Preparedness
5
FERC Order 831 – Energy Offer Cap
FERC has accepted MISO’s latest
compliance filing, subject to two language cleanup
changes
MISO will submit a compliance filing
addressing directed tariff language adjustments
Effective date: October 1, 2020
MISO has submitted a Tariff Waiver Request for
the upcoming winter, similar to previous years
Verified energy costs above $1,000/MWh
could be recovered via Revenue Sufficient Guarantee (RSG)
payments
Effective dates: 12/1/2018 – 4/30/2019
6
Offer Cap References
• MISO Tariff Waiver Request (2018-10-01 Docket No. ER19-27-00)
• FERC Acceptance of MISO’s Compliance Filing (2018-10-01 165
FERC ¶ 61,004 Docket No. ER18-622)
• MISO Order 831 Compliance Filing (2018-05-29 Docket No. ER18-
622-003)
• November 2017 MSC Update on FERC Order 831
• April 2017 MSC Update on FERC Order 831 Compliance Approach
• March 2017 MSC Update on the impacts of FERC Order 831
• August 2016 MSC Update on Offer Cap
• May 2016 MSC Tutorial on Offer Cap
7
Resource Assessment: Generation
Eric Rodriguez
9
MISO Preliminary 2018-19 Winter
Forecast
MISO WideReserve Margin Target
17%
Projected Reserve Margin 36%
Winter Peak Forecast 103 GW
Total Projected Available Capacity
140 GW
All-time Winter Peak:
109 GW on January 6th, 2014
Final assessment results will be presented at Winter Readiness Workshop on October 29
Adequate resources are projected to meet demand for Winter 2018-2019
NOAA forecasts warmer than normal temperatures for most of the MISO footprint
Forced Out [MW] Total Out [MW]
Average of 15 monthly peak hours 14,743 25,114
Max seasonal average of 5 seasons 21,708 32,912
Maximum peak day 25,802 38,618
Planned and Maintenance Outages are a significant portion of the total outages during past winters
10
0
5,000
10,000
15,000
20,000
25,000
30,000
35,000
40,000
Dec-13
Jan-14
Feb-14
Dec-14
Jan-15
Feb-15
Dec-15
Jan-16
Feb-16
Dec-16
Jan-17
Feb-17
Dec-17
Jan-18
Feb-18
MW
MISO generation outage totals during monthly peak hours
GADSMaintenanceOutages
GADS PlannedOutages
GADS ForcedOutages
Seasonal derates (~9 GW) are accounted for in the capacity values
140.7
44.025.1
18.8
5.8*
102.6
20
40
60
80
100
120
140
160
ProbableCapacity
(w/o S-N RDTL)
CoincidentPeak Forecast
ProbableReserves
(Pre-Outage)
Total Outages ProbableReserves
(Post-Outage)
139.7
42.125.1
17.0
5.0*
102.6
20
40
60
80
100
120
140
160
Base Capacity(w/o S-N RDTL)
CoincidentPeak Forecast
Base Reserves(Pre-Outage)
Total Outages Base Reserves(Post-Outage)
Total Outage Predictions based on 5-year winter outage data from GADS
11
*Capacity which was assumed non-transferrable from planning analysis is included
in MISO-wide outage results, to reflect total outage impact seen by operations
S-N RDTL: South-to-North/Central Regional Directional Transfer Limit
Under a high load and extreme outage scenario, MISO would rely on maximum generation procedures
12
*Capacity which was assumed non-transferrable from planning analysis is included
in MISO-wide outage results, to reflect total outage impact seen by operations
140.7
36.8 32.93.9
5.8*
109.8
20
40
60
80
100
120
140
160
ProbableCapacity
(w/o S-N RDTL)
90/10Coincident
Peak Forecast
High LoadReserves
(Pre-Outage)
Total HighOutages
High LoadReserves
(Post-Outage)
140.7
36.8 38.6-1.8
5.8*
109.8
20
40
60
80
100
120
140
160
ProbableCapacity
(w/o S-N RDTL)
90/10Coincident Peak
Forecast
High LoadReserves
(Pre-Outage)
Total ExtremeOutages
ExtremeReserves
(Post-Outage)
S-N RDTL: South-to-North/Central Regional Directional Transfer Limit
38%
62%
25.1
10.2 6.32.4
44.0
.0
5.0
10.0
15.0
20.0
25.0
30.0
35.0
40.0
45.0
50.0
ProbableReserves
TotalOutages
Generation BTMG+DR OperatingReserves
GW
13
Probable Outage
High Load High Outage
In a high load and high outage scenario, MISO would rely on BTMG and DR to meet peak demand
Emergency only resources(Steps 2b and above)
54%33%
13%
32.9
1.5 2.4
36.8
.0
5.0
10.0
15.0
20.0
25.0
30.0
35.0
40.0
High LoadReserves
Total HighOutages
Generation BTMG+DR OperatingReserves
GW
Pie charts represent breakdown of available post-outage resources
-10-505101520253035
Chance of LMRs Being Called for Winter 2018-19
Use of System-Wide Emergency Operating Procedures could be necessary if higher than normal load or forced outages reduces the available resource margin
14
Shaded area represents a 40% probability of realizing a Winter scenario requiring Emergency Operating Procedures
The red line represents 6.3 GW of potentially available Load Modifying Resources (LMRs)
and 2.4 GW of Operating Reserves
Questions?
Contact Info
• Eric Rodriguez
Resource Adequacy Coordination
(317) 249-5831
• Ryan Westphal
Resource Adequacy Coordination
(651) 632-8526
16
Generation Resource Assessment Appendix
Winter Resource Assessment Process
• Various forced outage scenarios studied
• Load Modifying Resource (LMR) availability
based on historical winter performance
• Regional transmission path contracts considered
18
Generation Load Reserves
Investigation of three winter resource and load scenarios show sufficient level of planning reserves
19
Total Probable Capacity includes 1.1 GW of MISO-North resources with Energy
Resource Interconnection Service (ERIS) without a firm point-to-point Transmission
Service Request (TSR)
These are “energy-only” resources not counted as capacity, but still are available to serve local load
in real-time operations
37.1
139.7102.6
20
40
60
80
100
120
140
160
TotalCapacity
CoincidentPeak Forecast
Base Reserves(Pre-Outage)
38.2
140.7
102.620
40
60
80
100
120
140
160
Total ProbableCapacity
CoincidentPeak Forecast
Probable Reserves(Pre-Outage)
31.0
140.7
109.8
20
40
60
80
100
120
140
160
Total ProbableCapacity
90/10 CoincidentPeak Forecast
High Load Reserves(Pre-Outage)
Base Scenario
20
Base Scenario
21
GVTC: Generation Verification Test CapacityTIS: Total Interconnection ServiceER: Energy ResourcesTSR: Transmission Service RequestBTMG: Behind The Meter GenerationDR: Demand Response
2.6 3.7
2.0 9.2.6 1.3 .0 15.1
1.92.5 .0 5.0 37.1
171.0
139.7
102.6
.0
20.0
40.0
60.0
80.0
100.0
120.0
140.0
160.0
180.0
GW
The need for emergency procedures will be impacted by the availability of resources
3.2
6.3
2.5
4.1
5.8
16.1
-5.8
-10 -5 0 5 10 15 20
Stranded Capacity
Capacity Imports
Load Modifying Resources
Wind Generation
GW
Counted as Winter Capacity Potentially Available Potentially Not Available
Resource Assessment: Transmission
Benny Relucio
Overview
• Why perform the Coordinated Seasonal Assessment (CSA)?
• Evaluate a variety of stressed conditions across the MISO
footprint
• Then provide system operators with guidance as to
possible but unlikely system conditions that would warrant
close observation to ensure system security
• Inform Real-Time Operations of potential limitations and
issues on the system for the upcoming winter
• Coordinate with other entities
• The limitations in the system were within the expected
norms for the upcoming winter
24
Overview
Overview – CSA Analyses
Steady-State AC Contingency
Analysis
• Evaluates the effect of simple and complex contingencies on the MISO footprint and Tier-1 areas
• IROL review
Thermal Analysis during Energy Transfer
Simulations
• First Contingent Incremental Transfer Capability (FCITC)
• Evaluates the impact of high MW transfers & identifies key flowgates and lines that may limit transfers
• 4 transfer analyses studied
Voltage Stability Analysis during Energy Transfer
Simulations
• Power-Voltage Analysis (PV)
• Analyzes high transfers in combination with transmission & generator outages which can cause stability issues across the footprint
• 4 High Voltage interfaces studied
Phase Angle Analysis during Energy Transfer
Simulations
• Identifies large phase angle differences associated with reclosing a transmission line
• Identify angle differences before and after an energy transfer
25
Steady-State AC Contingency Analysis
• Category P0 (Cat A) – system intact• Category P1 (Cat B)
• P1.1 (B1) – fault generator• P1.2 (B2) – fault transmission circuit• P1.3 (B3) – fault transformer• P1.4 – single shunt device• P1.5 (B4) – block single dc pole
• Stakeholders provided additional P2, P3, P6 and P7 contingencies they deemed beneficial to run for their areas
Contingencies
• No outstanding thermal or voltage issues identified that does not have mitigations by the operating transmission entity
• Interconnection Reliability Operating Limit (IROL) Screening:• No new or valid IROLs identified
Results
26
Thermal Transfer Analysis(FCITC)
AnalysisFCITC
(MW)Constraint
MISO CENTRAL Region West to East Transfer(Wilton Center to Dumont)
2,491
[AEP] Tanners Creek - [DEO&K] Miami Fort 345 kV ckt 1
for the loss of [DEO&K] Terminal - [DEO&K] East Bend 345 kV ckt 1
MISO CENTRAL Region East to West Transfer(Dumont to Wilton Center)
3,939[ITCT] Monroe 1&2- [ATSI] Lallendorf 345 kV for the
loss of [ATSI] Allen Jct - [METC] Morrocco 345 kV ckt 1
MISO Midwest (NORTH &
CENTRAL) to MISO SOUTH-186 [EMBA] Franklin - [EES] Bogalusa 500 kV ckt 1 for the
loss of [EMBA] Franklin - [EES] McKnight 500 kV ckt 1
MISO SOUTH to MISO Midwest
2,500 No Violations
27
CSA Transfer (FCITC) Historical Trend
28
Wilton Centerto Dumont
Dumont toWilton Center
MISOMidwest to
South
MISO Southto Midwest
2018-19 2491 3939 -186 2500
2017-18 5000 6000 3000 0
2016-17 5000 4949 0 0
2015-16 3657 5000 3000 0
-1000
0
1000
2000
3000
4000
5000
6000
7000
MW
Not Studied
Not Studied
Not Studied
Not Studied
Voltage Stability (PV) Analysis
• Down Stream of Gypsy (DSG) Interface• Western Interface• West of the Atchafalaya Basin (WOTAB) Interface• Fancy Point / Baton Rouge Area Interface
Interfaces Evaluated
• Each Interface underwent a transfer simulation with different case scenarios ranging from system intact to applying a known outage
• As Transfers occurred severe contingencies were applied• Results indicate that system limitations due to voltage
stability were within the expected norm for the entire spectrum of scenarios
Scenarios and Results
29
Voltage Stability (PV) Analysis
• First time for this Analysis based on the Fancy Point Operating Guide
• As Internal Area Generation was ramping down:• Voltage conditions observed • Flow on Fancy Point 500/230kV AT1 Transformer
measured
Fancy Point Area Interface
• Analysis illustrated the points where AT1 transformer overloads under various scenarios and contingencies
• Results verify the conditions laid out in the Fancy Point Operating Guide
Takeaway from Results
30
Phase Angle Analysis
• Measure the phase angle differences between 2 ends of a line:• first when it is closed • Then measure again when it opens (contingency)• Make measurement before & after an energy transfer• Report Phase Angles > 30 degrees
Procedure
31
MISO Operating
RegionTransfer Status Delta Bus Angle Line / Contingency
NORTHBefore° 41.0
[OTP] Center – [OTP] Prairie 345 kV ckt 1After° 45.8
NORTHBefore° -32.0
[OTP] Center – [OTP] Jamestown 345 kV ckt 1After° -37.4
SOUTHBefore° -25.9
[EES] Mt. Olive – [AEPW] Layfield 500 kV ckt 1After° -33.7
SOUTHBefore° -32.5
[EMBA] Franklin – [EES] Bogalusa 500 kV ckt 1After° -33.5
SOUTHBefore° -37.0
[AEPW] Crockett – [EES] Grimes 345 kV ckt 1After° -47.8
Contact Info
Benny [email protected]
(317) 249-5231
Kojo [email protected]
(651) 635-8461
2018-19 Winter CSA Results on the MISO Extranet (CEII NDA, UNDA Appendix A, &
Reliability Authority Approval Required)https://www.misoenergy.org/extranet/reliability-authority/planning-authority
Readiness
33
Each winter brings challenges that have to be closely monitored
34
Sustained cold temperatures
Fuel Limitations Frozen Equipment
Severe weather conditions
Forced Generation Outages
Rapid Load Pickups
Weather Uncertainty
Solar GenerationWind Generation
35
Gas-Electric Coordination
• Enhanced Operational Tools
• Gas-Electric Market Alignment
• Reliability & Pipeline Calls• Pipeline & Price Monitoring• Operational Situational Awareness
Emergency Preparedness
• MISO EOP & Winter Readiness Workshops
• Emergency Response & Power System Restoration Drill
• Emergency Procedures
MISO is well prepared to handle winter operations
Generation Portfolio
• Diverse generation pool to ensure
reliability
• Planning and collaboration with
members for generation utilization
Operational Readiness
• Communication, Coordination, Planning, and Training
• Generation Fuel Survey
• MISO Winterization Guidelines
• Enhancements
Obligations are successfully met through expertise, collaboration, and communication
Partnering with members to drill on emergency process ensures readiness in all operating situations
36
XML DRILL:• Last
Wednesday of each month @ 13:00 EST
• LBAs onlyFirm Load Shed Drill:
• 1st Wednesday of each month @ 13:00 EST
• LBAs only
EDR Drill:• 2nd Thursday of
each month @ 10:00 EST
LMR DRILL:• 2nd Tuesday of
each month @ 10:00 EST
• MPs only
LMM Drill:• 2nd Tuesday of
each month @ 10:00 EST
• LBAs only
Power Restoration Drills: Two Drills held each Fall.
FRIDAYMONDAY
Long-Lead Generation
Commitments
Generation Outages Rescheduled
Restored all Possible Transmission
Outages
Curtail Schedules
Reconfiguration Options
Emergency Generation
Load Management
Operating Reserves
Emergency Purchases
In Real-Time, unplanned outages and other unknowns may require emergency procedures to gain access to additional resources and ensure reliability
37
Ops PlanningOps Planning Cons Ops / AlertsCons Ops / Alerts Warning / EventWarning / Event
Load Shortage
Review load obligations against available resources and system
conditions
Take Actions to ensure reliability and avoid Load Shed
https://www.misoenergy.org/markets-and-operations/reliability-operating-procedures/#t=10&p=0&s=&sd=
Improved operating tools and resources help further Gas-Electric situational awareness
38
MISO Website: Gas Pipeline
Notifications Page
Fuel Impact Report: Potential
At Risk Units
Electric/Gas Pipeline Map
Display
Winter Generator Fuel Survey
Generator-Pipeline Database
Gas Usage Profiles FERC 809
• New MISO Gas / Electric Coordinator started October 1
• Delayed injections due to lingering spring cold and high
summer demand led to the lowest gas storage levels in 10
years
‒ However, strong production is offsetting low storage
levels and keeping prices flat
• 2 new large pipelines placed into service in October increase takeaway capacity
from the Marcellus and Utica Basins
• MISO 2018-2019 Winter Fuel Survey: October 1-26
‒ Identical survey questions to 2017
‒ Market Participant participation rate similar to last year (>80%)
‒ Final results presented at the December RSC Meeting
• No additional notable items to report for Winter 2018-19
Gas pipeline and storage access throughout the MISO footprint support winter generation needs
39
Additional enhancements to tools and processes position MISO to manage extreme circumstances
40
• Provides transparent price signals to procure ten minute reserves to return the RDT constraint to within limits following a generator contingency in the South
Enhanced Reserve Procurement on Regional
Directional Transfer
Aug 2018
• Supports unit commitments in the Baton Rouge/New Orleans area to prevent severe overloads on the Fancy Point transformer for N-1-1 events.
• Similar to other South Region load pockets like DSG, Amite South, and Western
Fancy Transformer Operating Guide
Aug 2018
• Works to ensure sufficient resources are available for Real-Time operations
Resource Availability and Need (RAN)
On-going
• Improves operational Electric-Gas situational awareness
Electric-Gas Tools and Resources
On-going
Winterization
41
42
MISO generators can protect against losing capacity by preparing
• Evaluation of Potential Problem Areas
• Detailed and Tested Winterization Plan
• Critical Instrument and Equipment Protection
• Fuel Availability Considerations
• Apply NERC’s winter generator reliability guidelines
• Utilize CROW outage scheduling system to account for cold weather impacts to unit performance and fuel availability
Extreme winter weather can contribute to significant losses of electric generation through frozen equipment and fuel procurement issues
It is essential to update MISO Outage Scheduler for cold weather impacts to unit performance, including fuel availability
• The MISO CROW (Control Room Operations Window) outage scheduling system is used to plan, receive, analyze, and report outages of transmission and generation facilities
Initiates Outage Coordination Studies /
Reviews
• BPM-008 Outage Operations
• Attachment D: Guidance on Selecting Appropriate Cause Codes for Outage Submission
Informs the Day Ahead Market of resource
participation
• BPM-002 Energy and Operating Reserve Markets
• Section 4.2.2
Method for downstream processes to know
availability of generation
• Transmission Security Planning
• Day Ahead and Forward Reliability Commitment Assessment
• Real Time
MISO is enhancing the Winterization Review Process, including communicating lessons learned and creating a Winterization Survey
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
GO/GOP updates
to CROW
Jan
End Winter Season
GO/GOP updates
to CROW and
GADS
Feb 28
Planning Resource
Auction
April 1-10
Final GO/GOP
GADS Updates
April
Completion of
Holistic Review of
Winter GADS
Outage Data
June
MISO Follow-Up on
Generator
Performance
July
MISO Follow-Up on
Generator
Performance and
Aug
Winter
Readiness
Workshop
Oct
Send Out
Winterization
Survey and Gas Fuel
Survey
Oct
Discuss Responses
to Winterization
Survey and
Determine
Resource
Availability Impacts
Nov
Begin Winter
Season
GO/GOP
updates to
CROW
Dec
Winter Survey (In Development) will help share industry lessons learned using past unit performance and lessons learned
Did this unit trip or experience any equipment freeze issues during the winter?
• Was this a reoccurring event or did it occur during a previous winter? If yes, explain in detail the cause.
• After examining the element(s) which froze or forced the trip previously – what measures has the plant taken to protect the element from freezing?
• Were these measures in effect when the equipment froze?
What lessons learned and improvements has the plant made?
• Explain the physical or operational improvements. Are lessons learned included in the weatherization plan?
Are there any outstanding work orders that relate to winter readiness that would prevent the unit from starting or could trip the unit during an extreme cold weather event?
45
Does the resource have a plan to prepare for winter?
Does the resource have a severe cold weather checklist?
Is there a maintenance procedure for confirming heat tracing is functioning properly?
Has the plant done a thorough inspection of all critical insulation?
Has plant management and maintenance personnel reviewed the NERC Guideline Generator Unit Winter Weather Readiness –Current Industry Practices V2?
Advanced planning and preparation for the winter season
Generator Winter Weatherization
47
Appendix
49
Energy Offer Cap
• Tariff waiver filed, as in previous years, to allow recovery of verifiable incremental energy costs in excess of the $1,000/MWh energy offer price cap
• Interim solution to FERC Order 831 compliance which will becomeeffective on Oct 1, 2020
Reference Levels
• Request consultation with IMM if reference levels aren’t reflective of costs or unit capabilities
CROW Outage Cause Codes
• Mandatory and based on outage priority
• Essential to implement MISO’s unit commitment plan and conduct post-event analysis
• Use specific codes in place of 115 Other
Reminders
Summary of FERC Order 831
• Cap each resource’s offer at the higher of $1,000/MWh (soft cap) or verified cost-based incremental energy offer
• Cap verified cost-based “equivalent” incremental energy offers at the hard cap of $2,000/MWh for setting energy prices
Revises the energy offer cap for resources, currently
set at $1,000/MWh
• Resource may be eligible for make-whole payment if verification cannot be completed before market close or for verified cost-based “equivalent” energy offers above $2,000/MWh
Offers will be verified by the IMM after market close
and before market processes run
• Waiver was filed for this winter, as for previous years
MISO and IMM are working to ensure system and software readiness for
implementation in Fall of 2020
50
51
Sample Future Lessons Learned
Plant A_CC1 tripped – loss of instrument air to main gas
supply valve due to moisture freezing in instrument air line.
� Root cause; steam side and air side check valves failed
Plant B_GT1 tripped – one of two rotor cooling air heat
exchanger transmitter froze, which caused a low level
condition.
� Root cause; lack of transmitter cabinet heater.
� Corrective action; plant to install cabinet heater.
Plant C_G1 tripped – sensing line level transmitter froze.
� Root cause; insulation missing.
� Corrective action; plant to install flexible wrap insulation.
Heat trace is not an option for this section of line.
52* Sample Lessons Learned obtained from ERCOT Public Weatherization Workshop
AccuWeather forecasts a mild beginning to the winter season
53
As of Oct 15, 2018
Operators use emergency procedures mitigate capacity concerns and maintain reliability
54
Emergency Operating Procedures
guide operator actions when an event has the potential to, or actually does, negatively impact system reliability
Conservative System
Operations
Severe Weather Alert
Hot Weather Alert
Cold Weather Alert
Geo-Magnetic
Disturbance Warning
Maximum Generation
Emergency Procedures
For more information - MISO Operating Procedures One-Pager and Appendix
MAXIMUM GENERATION EMERGENCY DETAILS
https://cdn.misoenergy.org/SO-P-EOP-00-002%20Rev%205%20MISO%20Market%20Capacity%20Emergency237357.pdf
Conservative System Operations Procedure
SO-P-NOP-00-449
https://cdn.misoenergy.org/SO-P-NOP-00-
449%20Rev%201%20Conservative%20System%20Operations237368.pdf
MISO Market Capacity
Emergency
SO-P-EOP-00-002
https://cdn.misoenergy.org/SO-P-EOP-00-002%20Rev%205%20MISO%20Market%
20Capacity%20Emergency237357.pdf
MISO’s operating procedures ensure reliability during emergency or abnormal operating situations Conservative Operations: If conditions warrant, MISO will transition from normal operating conditions to Conservative Operations to prepare local operating personnel for a potential event, and to prevent a situation or event from deteriorating
Emergency Operations: Emergency Operating Procedures (EOPs) guide system operator actions when an event occurs on the electric system that has the potential to, or actually does, negatively impact system reliability. EOPs are communicated in escalating order as alerts, warnings, and events
Cold Weather Alert Extreme temperatures forecasted
Severe Weather Alert Adverse weather conditions within the area
Conservative Operations Declarations Reliability issues may be possible
Maximum Generation Alert MISO forecasts a potential capacity shortage
Maximum Generation Warning Preparing for a possible event
Maximum Generation Event (Step 1) / EEA*1 Taking steps to preserve operating reserves
Maximum Generation Event (Steps 2, 3, 4) / EEA*2
Taking steps to preserve firm load
Maximum Generation Event (Step 5) / EEA*3
Actual event occurring - shed firm load and/or perform rolling brownouts or blackouts for defined area
57*NERC Emergency Energy Alert (EEA)
Conservative System Operations
• MISO is responsible for determining, declaring, coordinating (when time permits) and communicating Conservative System Operations for the purpose of maximizing MISO’s ability to operate the Bulk Electric System (BES) reliably during periods of extreme weather conditions and other abnormal circumstances that pose an imminent threat to the power grid.
• Five declarations are used to prepare operating personnel and facilities for extreme weather conditions or abnormal conditions that will, or have the potential to, impact the Bulk Electric System (BES):
58
Conservative System
Operations
Severe Weather Alert
Hot Weather Alert
Cold Weather Alert
Geo-Magnetic Disturbance
Warning
• Cold Weather Alert may or may not coincide with a Conservative System Operations declaration, and can be for any portion of the MISO system.
Cold Weather Alert
59
Cold Weather Alert
• TOPs and GOPs review plans to determine if any scheduled or in process maintenance or testing on monitoring, control, transmission, or generating equipment can be deferred or cancelled
• GOPs shall report and provide updates to the MISO Regional Generation Dispatcher (RGD) concerning all fuel/environmental limited resources for the duration of the Alert
Define boundaries of Alert Area and
start and end time of Alert period
Declare or update Conservative
System Operations as appropriate
Identify the amount of
available External Resources that
can be scheduled into the Alert area
Identify the amount of non-firm Export
Schedules from Alert area available for curtailment
during a Warning declaration
The purpose of the Max Gen Alert is to communicate system conditions for Operational Awareness. Steps in this level are designed to prepare entities for
actions during subsequent levels of the Max Gen process. Each level/step actions are exhausted, time permitting, prior to going to next step.
Maximum Generation Emergency - Alert Level
60
MPs to ensure energy interchange transactions sourcing or sinking in the
MISO Balancing Authority Area (MBAA)
are accurate
Maximum Generation Emergency - Alert Level
61
Determine amount of increased transfer
capability and/or amount of transmission
constraint stranded generation that can be
made available
MPs and LBAs ensure LMR
availability data, self-scheduled LMR and LMM
information in the MCS-LMR Tool is
updated and accurate
Coordinate with TOs to determine the availability of any transmission
system reconfiguration options in the shortage area
Issue any projections,
declarations, or specific
instructions via MCS
Communicate!
Ensure use of Economic Maximum Limits by
MISO processes (MPs to review limits and
ensure all ranges are offered)
Review Emergency Demand Response
(EDR) offers to determine availability.
Collect and review LMR availability via the MCS
LMR Tool
LBAs may issue public conservation
announcements and/or public appeals
Maximum Generation Emergency -Warning Level
62
Max Gen Warning indicates that Operating Reserve requirements may not be met in the near future without taking actions
MPs to ensure correct availability data is entered in the Tool
Maximum Generation Emergency - Warning Level
63
Instruct available External Resources (Module E registered Capacity Resources) to be
scheduled into the MBAA in the amount required to
relieve the shortage condition.
Curtail non-firm Export Schedules from the Warning Area in the
amounts required to relieve the shortage condition.
Instruct TOs to implement reconfiguration options expected to increase
transfer capability into the Warning Area and/or make
transmission constraint stranded generation
available in the amount required to relieve the
shortage condition.
Commit Generation Resources, DRR–Type 1 and DRR–Type 2 that are Available Max Emergency
(AME)
Implement Emergency Generation Limits
Declare NERC Energy Emergency Alert (EEA) Level 1 – All available Resources are in use
Maximum Generation Emergency - Event Level
64
When MISO cannot meet forecasted Energy and Operating Reserve requirements with Economic Maximum Limits
Declare NERC EEA Level 2 –
Load Management
in effect
Instruct Load to be reduced via Module E
Load Modifying Resources (LMRs) and reduction via
Load Management Measures –
Stage 1
Commit EDR offers,
available in the event
area, in merit order
Emergency purchases
from neighboring BAs (excess
energy)
Instruct LBAs to issue public
appeals to reduce demand
Maximum Generation Emergency - Event Level
65
Max Gen Event Step 2 is the implementation of Load Management actions. These resources include LMRs, LMMs, EDRs
Maximum Generation Emergency - Event Level
66
Supplemental, then spinning reserves are utilized as co-
optimized by Unit Dispatch System (UDS)
Instruct Load to be reduced by Load Management Measures – Stage 2 by
LBAs
- Reduction by LBA will be determined by prorated of total amount of resources available in Event Area
- Includes voltage reductions
Operating Reserves have been depleted. Use Load Management Measures Stage 2
Maximum Generation Emergency - Event Level
67
Implement Reserve Call from Contingency Reserve Sharing
Group
Implement additional Emergency energy purchases (typically from neighboring Balancing Authority's
Operating Reserves)
Maximum Generation Emergency - Event Level
68
Declare NERC EEA Level 3 –Firm Load interruption imminent or in progress
Direct Firm Load Shedding in the defined Event Area by LBA
Firm Load Shed in progress or imminent
Maximum Generation Emergency -Termination
69
Short-term forecasted Load returned below (and continuing
below) the sum of the economic
maximums of on-line Resources plus scheduled
interchange
Maximum Generation Event
is terminated
Generation Resources should verify they have
returned to normal economic
operating ranges
Steps taken during Maximum Generation Emergency will be restored in the reverse order from implementation
LMR Process & Steps taken by MISO & Market Participants (MPs) / Asset Owners (AOs)
70
