Winter Readiness Workshop. November 6, 2017

Transcription

1 Winter Readiness Workshop November 6,

2 2 Emergency Preparedness - Planning

3 Reminders FERC Order Energy Offer Cap Reference Levels CROW Outage Cause Codes Replaces the current hard energy offer cap of $1,000/MWh, with a soft cap of $1,000 and a hard cap of $2,000/MWh Offers will be verified by the IMM after market close and before market processes run MISO and IMM are working to ensure system and software readiness for implementation on December 1, 2017 (Additional details at Nov 9 MSC Meeting) Request consultation with IMM if reference levels aren t reflective of costs or unit capabilities Mandatory and based on outage priority Essential to implement MISO s unit commitment plan and conduct postevent analysis Use specific codes in place of 115 Other 3

4 Resource Assessment: Generation Darius Monson

5 MISO projects adequate resources to reliably meet demand for Winter MISO Preliminary 2017 Winter Forecast MISO Wide Reserve Margin Target 15.8% Base Reserve Margin* 35.7% Winter is forecasted to be warmer than normal in the Central and South, and normal to below normal in the North Projected Reserve Margin* Probable Reserves after Outages* Winter Peak Forecast Total Projected Available Capacity All-time Winter Peak: 109 GW - January 6, % to 37.3% 6.7% to 19.3% GW GW 5 *Range of projections reflect the uncertainty of parameters, such as resource outages, load, and limited transmission, that can t be known ahead of time

6 Winter Resource Assessment Process Generation Load Reserves Various forced outage scenarios studied Load Modifying Resource (LMR) availability based on historical winter performance Regional transmission path contracts considered 6

7 Investigation of 3 winter resource and load scenarios show sufficient level of planning reserves GW GW * Total Capacity Coincident Peak Forecast Base Reserves (Pre-Outage) Total Probable Capacity Coincident Peak Forecast Probable Reserves (Pre-Outage) * Total Probable Capacity includes 1.7 GW of MISO-North resources with Energy Resource Interconnection Service without a firm point-topoint Transmission Service Request. These are Energy Only resources not counted as capacity, but still are available to serve local load in real-time operations. GW * Total Probable Capacity 90/10 Coincident Peak Forecast High Load Reserves (Pre-Outage)

8 Planned and Maintenance Outages are a significant portion of the total outages during past winters 35,000 30,000 GADS Mntnce Outages GADS Planned Outages GADS Forced Outages 25,000 20,000 MW 15,000 10,000 5,000 0 Dec- 12 Jan- 13 Feb- 13 Dec- 13 Jan- 14 Feb- 14 Dec- 14 Jan- 15 Feb- 15 Dec- 15 Jan- 16 Feb- 16 Dec- 16 Jan- 17 Feb- 17 Forced Out [MW] Total Out [MW] Average of 15 monthly peak hours 12,942 (Dec-12~Feb-17 23,339 (Dec-12~Feb-17) Max seasonal average of 5 seasons 15,850 (Dec-12~Feb-17) 25,469(Dec-12~Feb-17) Maximum peak day 21,409 (Jan-14) 28,738 (Dec-16) 8

9 Total Outage Predictions based on 5-year winter outage data from GADS 160 Base Reserve Margin Scenario Probable Reserve Margin Scenario 16.8% Reserve Margin with Outages % Reserve Margin with Outages * *^ Base Capacity (w/out S-N Limit) Coincident Peak Forecast Base Reserves (Pre-Outage) Total Outages (Forced, Mntnce, Planned) Base Reserves (Post-Outage) Probable Capacity (w/out S-N limit) Coincident Peak Forecast Probable Reserves (Pre-Outage) Total Outages (Forced, Mntnce, Planned) Probable Reserves (Post-Outage) *Capacity which was assumed non-transferrable from planning analysis is included in MISO-wide outage results, to reflect total outage impact seen by operations. ^There is 0.9 GW of additional Energy Only resources in the MISO-S region which can be expected to serve local load in real time operations. 9

10 160 Under high load and extreme outage scenarios, like the Polar Vortex, MISO would need to rely on Maximum Generation procedures High Load High Outage Scenario 9.6% Reserve Margin with Outages 160 High Load Extreme Outage Scenario 6.7% Reserve Margin with Outages *^ *^ Probable Capacity (w/out S-N Limit) 90/10 Coincident Peak Forecast High Load Reserves (Pre-Outage) High Outages (Forced, Mntnce, Planned) High Load Reserves (Post-Outage) Probable Capacity (w/out S-N Limit) 90/10 Coincident Peak Forecast High Load Reserves (Pre-Outage) Extr. Outages (Forced, Mntnce, Planned) Extreme Reserves (Post-Outage) *Capacity which was assumed non-transferrable from planning analysis is included in MISO-wide outage results, to reflect total outage impact seen by operations. ^There is 0.9 GW of additional Energy Only resources in the MISO-S region which can be expected to serve local load in real time operations. 10

11 In high load and extreme outage scenarios, MISO may need to rely on Behind-the-Meter and Demand Response to meet peak demand Probable Outage Scenario % Reserve Margin with Outages BTMG+DR 30% Operating Reserves 12% Generation 58% GW Probable Reserves Emergency only resources (Steps 2b and above) Total Outages Generation BTMG+DR Operating Reserves Extreme Outage Scenario Generation 0% Operating Reserves 33% BTMG+DR 67% GW High Load Reserves 6.7% Reserve Margin with Outages 28.7 Extreme Total Outages 0.0 Emergency only resources (Steps 2b and above) Generation BTMG+DR Operating Reserves 11

12

13 Contact Info Darius Monson Resource Adequacy Coordination (651) Ryan Westphal Resource Adequacy Coordination (651)

14 Generation Resource Assessment Appendix

15 Base Scenario 15

16 Base Scenario GVTC: Generation Verification Test Capacity TIS: Total Interconnection Service ER: Energy Resources TSR: Transmission Service Request BTMG: Behind The Meter Generation DR: Demand Response GW

17 Resource Assessment: Transmission Katie Hulet

18 Overview Overview Why perform the Coordinated Seasonal Assessment (CSA)? Evaluate a variety of stressed conditions across the MISO footprint Inform Real-Time Operations of potential limitations and issues on the system for the upcoming winter Coordinate with other entities No outstanding issues were identified for this upcoming winter 18

19 Overview CSA Analyses Steady-State AC Contingency Analysis First Contingent Incremental Transfer Capability (FCITC) Analysis Critical Interface Voltage Stability (PV) Analysis Phase Angle Analysis Evaluates the effect of simple and complex contingencies on the MISO footprint and Tier-1 areas IROL review Evaluates the impact of high MW transfers and identifies key flowgates and interfaces that may limit transfers 3 transfer analyses and Wind Generation Sensitivity studied Analyzes high transfers in combination with transmission and generator outages which can cause stability issues across the footprint 4 PV interfaces studied Identifies large phase angle differences associated with reclosing a transmission line 19

20 Steady-State AC Contingency Analysis Contingencies 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 Results No outstanding thermal or voltage issues identified Interconnection Reliability Operating Limit (IROL) Screening: No new IROLs identified Nuclear Plant contingencies: No constraints identified 20

21 Transfer (FCITC) Analysis Analysis Wilton Center to Dumont Transfer Dumont to Wilton Center Transfer MISO Midwest (North & Central) to MISO South FCITC (MW) >5000 > * Constraint [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 [ITCT] Monroe [ATSI] Lallendorf 345 kv ckt 1 for the loss of [METC] Morocco [ATSI] Allen Jct 345 kv ckt 1 [EES-EMI] Franklin - [EES] Bogalusa 500 kv ckt 1 for the loss of [EES] McKnight - [EES-EMI] Franklin 500 kv ckt 1 *The Regional Directional Transfer Limit for real-time flows from MISO Midwest to MISO South is 3000 MW 21

22 CSA Transfer (FCITC) Historical Trend MW Wilton Center to Dumont Dumont to Wilton Center MISO Midwest to South Not Studied

23 Wind Generation Sensitivity MISO North Region Wind MISO Central Region Non-Wind Limiting Constraint: [ITCM] Ottumwa - [ITCM] Wapello 161 kv ckt 2 for the loss of [ITCM] Ottumwa - [ITCM] Wapello 161 kv ckt 1 FCITC: 3,469 MW 23

24 Critical Interface Voltage Stability (PV) Analysis Interfaces Evaluated Grand Gulf Stability Guide Down Stream of Gypsy (DSG) HV Interface Western HV Interface West of Atchafalaya Basin (WOTAB) Interface Scenarios and Results Each Interface was evaluated with a variety of scenarios ranging from system intact to applying a known outage with the most severe contingency Results indicate that the system voltages behave as expected for the entire spectrum of scenarios 24

25 Phase Angle Analysis MISO North to South Biased Case MISO Operating Region Delta Bus Angle Contingency English Name Stakeholder Comment CENTRAL NORTH 54.4 NORTH 35.2 NORTH SOUTH [WEC] Charter Steel Industrial 138 kv [WEC] CedarSauk 138 kv ckt 1 [XEL] Mallard 115 kv [WAPA] CPEC-Rutheville 115 kv ckt 1 [MP] Zemple 230 kv [OTP] Cass Lake 230 kv ckt 1 [MP] Zemple 230 kv [MP] CLAY BOSWELL 230 kv ckt 1 [EES] Mcknight 500 kv [SOCO] Daniel 500 kv ckt 1 Mitigated by Under Voltage Load Shed at Charter Steel Increase AC injection around Coal Creek/Center Reduce generation to reduce phase angle Reduce generation to reduce phase angle Reduce generation to reduce phase angle 25

26 Contact Info Katherine Hulet (651) Benny Relucio (317) Winter CSA Results on the MISO Extranet (CEII NDA, UNDA Appendix A, & Reliability Authority Approval Required): Winter CSA Results on the MISO Public Site:

27 27 Emergency Preparedness - Readiness

28 Extreme conditions can challenge MISO operations Polar Vortex January 2014 Tropical Storm Cindy June 2017 Solar Eclipse August 2017 Hurricane Harvey August 2017 Freezing Tested Hurricane Effectively MISO used components and Action Plan and managed a Hurricane Action fuel restrictions led provided an decrease in solar Plan developed with to improved electric- opportunity to energy and drop in members to gas coordination, practice lessons load, driven by successfully outage reporting, learned from human behavior manage this rain and winter readiness Hurricane and weather and flooding event preparations Readiness Drills patterns 28

29 but operators are well prepared to make quick and complex decisions when handling all operating situations Gas-Electric Coordination Initiatives Enhanced Operational Tools Gas-Electric Market Alignment Generation Fuel Survey MISO Winterization Guidelines Operational Situational Awareness Generation Portfolio Diverse generation pool to ensure reliability Planning and collaboration with members and gas industry for wind and natural gas utilization Emergency Preparedness FERC Winter Readiness Technical Conference MISO EOP & Winter Readiness Workshops Emergency Response & Power System Restoration Drill Operational Readiness Simulator training, Certification, and Continuing Education Strong Situational Awareness Robust Operational Tools and Procedures Operational & Market Enhancements 29

30 Operational and market enhancements also improve MISO s preparedness Coordinated Transaction Scheduling Improves transactions between MISO and PJM Oct 2017 Pricing Ramp Product May 2016 Provides transparent price signals to help manage ramp constraints that could lead to short-term reserve scarcity events Emergency Pricing Phase II Jul 2017 Off-line fast start resources amortized over minimum run time Available Maximum Emergency units allowed to move down below their Economic Minimum limits FERC Order 809 Nov 2016 MISO implemented changes to its Day Ahead Market to align with the Gas industry Gas-Electric Coordination Data Sharing with gas system operators Aug 2017 Enhances MISO s ability to coordinate with pipelines, especially during constrained operating conditions Gas Usage Profiles Target Nov 2017 Share Day-Ahead gas burn estimates with pipelines connected to MISO generators 30

31 MISO continues to conduct monthly Operation Drills MONDAY FRIDAY LMR DRILL: 2 nd Tuesday of each 10:00 EST MPs only LMM Drill: 2 nd Tuesday of each 10:00 EST LBAs only XML DRILL: Last Wednesday of each 13:00 EST LBAs only Firm Load Shed Drill: 1 st Wednesday of each 13:00 EST LBAs only EDR Drill: 2 nd Thursday of each 10:00 EST Power Restoration Drills: Two Drills held each Fall. 31

32 Electric-Gas Coordination Mark Thomas

33 Executive Summary National Storage Levels are near last year s, but slightly below 5 year average New gas supply heading into MISO, but could be cut if scheduled on interruptible transportation contracts MISO has implemented operational tools and strategic initiatives to increase situational awareness MISO is releasing Winterization Guidelines to promote generator winter preparedness 33

34 Strong Storage Levels Should Support Winter Operations Storage expected to peak just below 5-year average around 3.8 Tcf Unseasonably high injections during weeks surrounding hurricanes Harvey and Irma due to lower levels of power generation demand Even though injection season has lagged, NYMEX gas prices have remained under $3.00/MMBtu going into winter 34

35 Winter Outlook Increased Competition for Natural Gas in Winter Local Distribution Companies (LDCs) & Firm Shippers utilizing reserved firm transportation capacity contracts Potential limits on Interruptible transportation and flexible services Increase in gas-fired generation competing for same transportation space Pipeline Supply New expansions, such as Rover Pipeline, bringing gas to MISO New pipeline capacity is approved and built on Firm Transportation commitments Cold weather increases risk of production freeze-offs and compressor de-rates, threatening supply Rover Pipeline, Energy Transfer 35

36 Electric Gas Operations Tools

37 MISO actively monitors the Pipeline Network and Gas Industry activities MISO s Gas Pipeline Notifications Website provides regional insight into pipeline operating conditions Scrapes 35 MISO Pipeline EBB s for Critical Postings Useful for Market Participants and MISO Staff One Location, Regional Insight Critical Postings are issued if supply, capacity, or operational flexibility is impacted > Markets and Operations > Gas Pipelines ions/pages/gaspipeline.aspx 37

38 Fuel Impact Report: At Risk Units Internally, MISO will be monitoring the Pipeline Notification Website daily and will be translating relevant Critical Notices MISO will attempt to identify units that may be impacted and classify them as At Risk based on available information Internal classification will not impact unit status or Market Participant s portal submissions

39 Control Room Electric/Gas Pipeline Real Time Display Further interpretation and Leveraging of: Pipeline Notification Website Fuel Impact Report Pipeline Map Display with Additional Generator data included Daily Interpretation of pipeline conditions Pipeline Critical Notices will be translated and visually interpreted on Display - Serve as quick reference for Operators - Provide visual of restrictions - Additional Tool for insight into potential fuel limitations - Improves Awareness

40 Recent Initiatives

41 Generator-Pipeline Database Upgrade MISO commercial model updated with information provided by Market Participants holding natural gas generation Coordinated market participant outreach with Customer & Asset Registration Services MISO now has complete database of pipeline connections and dual fuel capability for all gas generators 41

42 Gas Usage Profiles Project Gas system operators will receive customized daily summaries of usage forecasts based on the MISO day-ahead clearings of interconnected generators Forecasted daily totals and hourly profiles MISO will coordinate with participating gas pipelines/local Distribution Companies (LDCs) to develop the most effective gas usage aggregations for each system 42

43 MISO Winter Generator Survey 4th annual implementation of the survey which was made available from October 2 nd November 3 rd, 2017 The highest participation rate of 87% (63,600 MW of capacity reporting) was reached during last year s survey survey was more user friendly, no significant changes to questions 43

44 MISO Winterization Guidelines Extreme cold temperatures can contribute to significant losses of electric generation MISO generators can protect against losing capacity by preparing for potential freeze offs of equipment Evaluation of Potential Problem Areas Detailed and Tested Winterization Plan Critical Instrument and Equipment Protection Fuel Availability Considerations 44

45 MISO urges asset owners to weatherize their generating units Follow the recommendations of North American Electric Reliability Corporation (NERC) Reliability Guideline: Generating Unit Winter Weather Readiness Review A Message from MISO on Weatherization on the MISO Website MISO Winterization Guidelines 45

46 Contact Info Mark Thomas Gas/Electric Operations Coordinator Please complete the Winter Generator Fuel Survey by November 4 th

47 Market Participant Winterization Presentation Duke Energy Bill Luke General Manager - Cayuga Generation Station Brian Wininger Technical Manager Cayuga Generation Station Jason Myers Operations Superintendent Cayuga Generation Station 47

48 48 Emergency Preparedness - Application

49 Each winter brings challenges that have to be closely monitored Sustained cold temperatures Fuel Limitations Frozen Equipment Insufficient Preparation Rapid Load Pickups Severe weather conditions Forced Generation Outages Wind Generation Solar Generation 49

50 Real-Time operating procedures are followed to efficiently provide least cost energy and maintain reliability of the Bulk Electric System Normal Operating Procedures Anticipate and plan ahead for "normal" system conditions Abnormal Operating Procedures Infrastructure or software system problems that affect MISO or its members Emergency Operating Procedures Emergency conditions that negatively impact system reliability 50

51 Emergency operating procedures preserve the system and gain access to certain resources during emergency or abnormal operating situations Emergency Operating Procedures guide operator actions when an event has the potential to, or actually does, negatively impact system reliability Maximum Generation Emergency Procedures Conservative System Operations Geo-Magnetic Disturbance Warning Severe Weather Alert Tier I Emergency Price Offer Floor Cold Weather Alert Hot Weather Alert Tier II Emergency Price Offer Floor 51 For more information - MISO Operating Procedures One-Pager and Appendix

52 Operators used emergency procedures to reliably manage the heat wave experienced in late September 52 Operating Day 09/21/ o F 09/22/ o F 09/23/ o F 09/24/ o F 09/25/ o F Peak Load GW GW GW GW GW Wind at Peak 8.8 GW 9.2 GW 4.8 GW 5.4 GW 1.9 GW NSI at Peak (Imports) 9.7 GW 11.8 GW 9.5 GW 7.2 GW 7.2 GW Cons Ops 11:00 EST Terminated 09/26 20:00 EST Max Gen Alert 12:00 20:00 EST 12:30 18:15 EST 13:00 17:15 EST 13:00 19:00 EST Max Gen Warning Max Gen Event 1a Max Gen Event 1bc 14:00 18:15 EST 14:30 18:15 EST 14:00 17:15 EST Record temperatures, high load, and seasonal and forced outages were contributing factors to the challenging conditions

53 Additional enhancements to tools and processes will better position MISO to manage extreme circumstances Improvement Area Transmission Load Relief (TLRs) Mitigation Issue Summary Other solutions are available to locally manage congestion, without the far-reaching impacts of TLRs. MISO is drafting a white paper v suggesting that for FERC re-examine the use of TLRs to manage congestion. Outage vanalysis Mid-Term: Generator Outage Capacity Tool Enhance Long-Term: Weather Tools Import and application processes to are include not designed more weather for parameters, this level of which uncertainty. are currently The Market available System from weather vendors, Enhancement into load includes forecasting projects system that IT will Agile be able backlog to serve as the foundation for improvements to address this issue. Generation Outage v Tariff Authority Enhance Work with Weather Stakeholders Import application to evaluate to include Tariff changes more weather to parameters, remove restrictions which are on currently MISO s available ability to from move weather generation vendors, outages into based load on forecasting capacity system and risk IT level. Agile backlog Forecasting Enhancements v Enhance Weather Weather Import Import application application to include to include more more weather weather parameters, parameters, which are currently look into available probabilistic from (90/10) weather forecast information, vendors, into and load Scenario forecasting analysis system with IT Agile Forecast backlog Monitor software 53

54 MISO plans for, monitors, and responds to changing system conditions throughout the day Obligations are successfully met through expertise, collaboration, and communication 54

55 Contact Info Rick Stachowicz Shift Operations Trevor Hines Shift Operations

56 Appendix

57 One-Pagers 57

58 MAXIMUM GENERATION EMERGENCY DETAILS PAGERS/ONE%20PAGER%20-%20MISO%20OPERATING%20PROCEDURES.PDF

59 Conservative System Operations Procedure SO-P-NOP sitory/procedure/so-p-nop %20rev%200%20conservative%20 System%20Operations.pdf MISO Market Capacity Emergency SO-P-EOP tory/procedure/so-p-eop %20rev%203%20miso%20market% 20Capacity%20Emergency.pdf

60 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 Severe Weather Alert Conservative Operations Declarations Maximum Generation Alert Maximum Generation Warning Maximum Generation Event (Step 1) / EEA*1 Maximum Generation Event (Steps 2, 3, 4) / EEA*2 Maximum Generation Event (Step 5) / EEA*3 Extreme temperatures forecasted Adverse weather conditions within the area Reliability issues may be possible MISO forecasts a potential capacity shortage Preparing for a possible event Taking steps to preserve operating reserves Taking steps to preserve firm load Actual event occurring - shed firm load and/or perform rolling brownouts or blackouts for defined area 60 *NERC Emergency Energy Alert (EEA)

61 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): Conservative System Operations Severe Weather Alert Hot Weather Alert Cold Weather Alert Geo-Magnetic Disturbance Warning 61

62 Cold Weather Alert 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 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 62

63 To gain access to certain resources, MISO must progress through its Maximum Generation Emergency Procedures Tier I Offer Floor Event - Step 1: a) Commit AME b) Implement Emergency Max Limits c) Declare NERC Energy Emergency Alert (EEA) 1 - All available non-emergency resources in use Tier II Offer Floor Event Step 2: a) Declare NERC EEA 2 - Load Mgmt procedures in effect b) Implement LMR (BTMG & DR) & Load Management Measures (LMM) Stage 1 c) Commit Emergency Demand Response (EDR) d) Implement Emergency Energy Purchases Event - Step 3: a) Utilize Operating Reserves b) Instruct load reduction of Load Management Measures (LMM) Stage 2 63 For more information - MISO Operating Procedures One-Pager and Appendix

64 Maximum Generation Emergency - Alert Level 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. 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 MPs to ensure energy interchange transactions sourcing or sinking in the MISO Balancing Authority Area (MBAA) are accurate 64

65 Maximum Generation Emergency - Alert Level Communicate! 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 65

66 Maximum Generation Emergency - Warning Level Max Gen Warning indicates that Operating Reserve requirements may not be met in the near future without taking actions Collect and review LMR availability via the MCS LMR Tool 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. MPs to ensure correct availability data is entered in the Tool LBAs may issue public conservation announcements and/or public appeals 66

67 Maximum Generation Emergency - Warning Level Step 1: Instruct available External Resources (Module E registered Capacity Resources) to be scheduled into the MBAA in the amount required to relieve the shortage condition. Step 2: Curtail non-firm Export Schedules from the Warning Area in the amounts required to relieve the shortage condition. Step 3: 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. 67

68 Maximum Generation Emergency - Event Level When MISO cannot meet forecasted Energy and Operating Reserve requirements with Economic Maximum Limits 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 68

69 Maximum Generation Emergency - Event Level Max Gen Event Step 2 is the implementation of Load Management actions. These resources include LMRs, LMMs, EDRs 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 69

70 Maximum Generation Emergency - Event Level Operating Reserves have been depleted. Use Load Management Measures Stage 2 Supplemental, then spinning reserves are utilized as cooptimized 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 70

71 Maximum Generation Emergency - Event Level Implement Reserve Call from Contingency Reserve Sharing Group Implement additional Emergency energy purchases (typically from neighboring Balancing Authority's Operating Reserves) 71

72 Maximum Generation Emergency - Event Level Firm Load Shed in progress or imminent Declare NERC EEA Level 3 Firm Load interruption imminent or in progress Direct Firm Load Shedding in the defined Event Area by LBA 72

73 Maximum Generation Emergency - Termination Steps taken during Maximum Generation Emergency will be restored in the reverse order from implementation Short-term forecasted Load returned below (and continuing below) the sum of the economic maximums of online Resources plus scheduled interchange Maximum Generation Event is terminated Generation Resources should verify they have returned to normal economic operating ranges 73

74 LMR Process & Steps taken by MISO & Market Participants (MPs) / Asset Owners (AOs) 74