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ERCOT Market Education
Intermittent Renewable Resources
2
This presentation provides a general overview of the Texas Nodal Market and is not intended to be a substitute for the ERCOT Protocols, as amended from time to time. If any conflict exists between this presentation and the ERCOT Protocols, the ERCOT Protocols shall control in all respects.
For more information, please visit:
http://www.ercot.com/mktrules/nprotocols/
Protocol Disclaimer
Housekeeping
3
• Restrooms
• Refreshments
• Attendance sheet
• Questions
Housekeeping
Please silence smart phones & other electronics
Course Introduction
5
This course is intended for personnel responsible for registering, operating and marketing Intermittent Renewable Resources (IRRs) in ERCOT
Includes:
• Resource Entities
• Qualified Scheduling Entities
• ERCOT staff
Course Audience
6
• Differentiate between IRRs and other generation technologies in ERCOT
• Identify the unique telemetry requirements of IRRs
• Describe the operational requirements for IRRs
• Summarize how IRR capabilities are forecast
• Summarize how IRRs are dispatched
• Describe a few Settlement impacts for IRRs
Upon completion of this course, you should be able to:
Course Objectives
7
Course Modules
Resource Landscape in ERCOT1
2 Market Provisions and Requirements for IRRs
3 IRR Forecasting
4 IRRs in Market and System Operations
5 Financial Settlements of IRRs
Modules in this course include:
6 MIS Reports for IRRs
Module 1
Resource Landscape in ERCOT
9
• Installed capacity and energy produced by fuel type
• Landscaping trends
• A few definitions
Topics in this module ...
Module Topics
10
The Generation Resource Landscape
Natural Gas53.3%
Coal20.5%
Wind19.6%
Nuclear5.0%
Other1.6%
2017 Installed Capacity
Natural Gas38.9%
Coal32.2%
Wind17.4%
Nuclear10.8%
Other0.8%
2017 Energy Produced
Total 78,251 MW
Total 357 million
MWh
Peak Demand Record: 73,308 MW on July 19, 2018
11
Landscape Trends
Natural Gas56%
Coal23%
Wind13%
Nuclear7%
Other1%
2011 Installed Capacity
Natural Gas39%
Coal39%
Wind9%
Nuclear12%
Other1%
2011 Energy Produced
Total72,349 MW
Total 334 million
MWh
Peak Demand in 2011: 68,305 MW on August 3, 2011
12
ERCOT Wind Generation (as of January 2018)
13
ERCOT Utility-Scale Solar Generation (as of January 2018)
14
Intermittent Renewable Resource (IRR) – A Generation Resource that can only produce energy from variable, uncontrollable Resources, such as wind, solar, or run-of-the-river hydroelectricity.
Currently, two types:
• Wind-Powered Generation Resource (WGR)
• PhotoVoltaic Generation Resource (PVGR)
A Few Definitions
Typically, WGRs and PVGRs are aggregations of Wind Turbines or Photovoltaic equipment
15
A Resource Entity may aggregate Intermittent Renewable Resource generation equipment together to form a single IRR.
General Rules:• Same Electrical Bus
• Generally, same model and size1
• Does not reduce ERCOT’s ability to model
Aggregation to form IRRs
1 See Protocol 3.10.7.2 (11) for exceptions
16
IRR Group – A group of two or more IRRs whose performance in responding to Security-Constrained Economic Dispatch (SCED) Dispatch Instructions will be assessed as an aggregate
• All IRRs must have the same Resource Node
• No Split Generation Resources
One More Definition
IRR1
IRR2
ERCOT
ERCOT-Polled Settlement (EPS) Meter
Resource Node
IRR Group
17
A Resource Entity wants to build a single generation site with both wind generation and photovoltaic systems
Class Discussion
IRR Definitions Test Drive
1. Can they create a single IRR?
2. Can they create an IRR Group?
No – Equipment is too dissimilar. Must be two IRRs
Yes – Assuming that the two IRRs can be set up with the same Resource Node.
Module 2
Market Provisions and Requirements for IRRs
19
• What makes IRRs unique?
• Impacts to ERCOT
• General IRR operating requirements
Topics in this module ...
Module Topics
20
What Makes IRRs Unique?
Variability Location Technology
Intermittent Energy Supply
Large and Sudden Ramps
Capacity Uncertainty
Transmission Constraints
Subsynchronous Resonance
Not Synchronous Generators
Limited Governor Control
21
What Makes IRRs Unique?
Variability
Intermittent Energy Supply
Large and Sudden Ramps
Capacity Uncertainty
Challenges
• Dispatching to a Base Point
• Managing Variances
22
IRR Dispatch
Intermittent Energy Supply Wind and Solar Energy – Use it or Lose it
• Non-IRRs chase their Base Points
• IRRs chase their energy supply
• Run at max capability (unless curtailed)
• Base Point is permissive
23
Managing Variances
Intermittent Energy Supply
ERCOT responds to variability with Regulation Service
Regulation matches generation with demand by responding to changes in system frequency
But how much Regulation does ERCOT need?
Is the amount impacted by IRRs?
24
Net Load
Load
Net Load
Non-Coastal Wind
Coastal WindSolar
Regulation manages risk of changes in Net Load
Intermittent Energy Supply
IRR outputs are subtracted from System Load to derive Net Load
25
• Hourly need based on two years’ history for the same month
Max
• Incremental MWs for additional Wind Generation 1
Regulation Impact
95th percentile of Regulation deployed 95th percentile Net Load changes
Intermittent Energy Supply
Continued IRR growth may impact Regulation requirements
1 Details in Methodology for Determining Minimum Ancillary Service Requirements
26
What Makes IRRs Unique?
Variability
Intermittent Energy Supply
Large and Sudden Ramps
Capacity Uncertainty
Challenges
• Energy supply may change dramatically at times
• IRRs have nearly instantaneous ramp rates
27
Energy Supply Ramp
Large and Sudden Ramps Dramatic changes in Energy Supply
Wind Output 12/19/2017
28
Impact of Energy Supply Ramp
Large and Sudden Ramps
• Regulation manages Net Load changes
• Non-Spin manages under-forecast Net Load ramp
May impact ERCOT procurement of Regulation and Non-Spin Reserves
Load
Wind
MW
Hour
Periods of increasing load with decreasing wind may put system
at ramping risk
29
IRR Ramp Rates
Time (seconds)0 +100 +200 +300
60.000
60.050
59.950
60.025
59.975
Time (seconds)0 +100 +200 +300
60.000
60.050
59.950
60.025
59.975
Large and Sudden Ramps With nearly instantaneous ramp rates …
Frequency could dip when IRRs curtailed
Frequency could spike when curtailment released
30
IRR Ramp Rate Limits
Large and Sudden Ramps
IRRs ramp rates limited to 20% of Nameplate Rating per minute
FullOutput
5 minutes
ZeroOutput
When curtailed by ERCOT
When released from curtailment by ERCOT
FullOutput
5 minutes
ZeroOutput
31
What Makes IRRs Unique?
Variability
Intermittent Energy Supply
Large and Sudden Ramps
Capacity Uncertainty
Challenges
• Difficult to predict available capacity for future hours
• Peak capacity may not coincide with peak demand
32
Predictability
Centralized IRR Forecasting
• ERCOT is responsible for IRR forecasting
• Consistent methodology for all IRRs
Capacity Uncertainty
More details on forecasting later in the course
33
Telemetry to Enhance Predictability
More telemetry data for IRRs means better forecasting
• Meteorological Tower Data from each site
• Detailed equipment status
• Wind turbines in service
• Inverters in service
Capacity Uncertainty
In-Service Out Unknown
Turbines 42 2 1
Inverters 28 1 1
34
Peak Capacity and Peak Demand
IRR capacity may not peak when most beneficial to the system
Capacity Uncertainty
Load
Net Load
Non-Coastal Wind
Coastal WindSolar
35
Wholesale Storage Loads
Wholesale Storage Load
Generation(May be IRR)
OtherLoad Metered
separately
EPSMeter
Wholesale Storage Loads may help Capacity Uncertainty
Basic Idea:1. Store energy when not needed2. Release later when needed
36
What Makes IRRs Unique?
Challenges
• Interconnection in remote areas
• Interconnection in weak areas
Location
Transmission Constraints
Subsynchronous Resonance
37
Potential Constraints
Potential constraints highlighted in Full Interconnection Study (FIS)
Transmission Constraints
FIS Study Report includes:
• Nature of constraints• Stability• Overload
• Base Case• Contingency Case
• Severity of constraints
38
What Makes IRRs Unique?
Challenges
• Series compensated lines increase likelihood of resonance at frequencies below 60Hz
• Resonance may damage generators
Location
Transmission Constraints
Subsynchronous Resonance
Generator(May be IRR)
Line Impedance
Series Capacitor
System Load
39
Initial Assessment
New Interconnecting Generation Resources
• Initial SSR1 screening by ERCOT
• Vulnerability Assessment by TSP if needed
Subsynchronous Resonance
1Subsynchronous Resonance
If countermeasures are required,
• Interconnecting Entity responsible
• Must be implemented prior to Initial Synchronization
40
Annual Re-Assessment
Resources in the Planning Model
• Annual SSR1 Review by ERCOT
• Vulnerability Assessment by TSP if needed
Subsynchronous Resonance
If countermeasures are required,
• TSP responsible
• Must be implemented by latter of1. Completion of transmission project 2. Initial Synchronization
1Subsynchronous Resonance
41
What Makes IRRs Unique?
Challenges
• All Generation Resources must provide Reactive Power
• Induction generators and photovoltaic panels don’t produce reactive power
Technology
Not Synchronous Generators
Limited Governor Control
MVAR
MW
42
Voltage Support
IRRs must provide Reactive Power
Operating at or above 10% Nameplate Rating• Support voltage set point at POI1
• Up to Unit Reactive Limit (URL)
Not Synchronous Generators
If output is below 10% of Nameplate, ERCOT may
request shutdown Leading
LaggingMW
MVAR
Typical Generator
Max MW at .95 PF
URL
URL
1 Point of Interconnect
43
What Makes IRRs Unique?
Challenges
• All Resources must provide Primary Frequency Response
• IRRs don’t have traditional governors (if any)
Technology
Not Synchronous Generators
Limited Governor Control
44
A Governor by any other name . . .
IRRs must provide equivalent governor response to stabilize frequency
Limited Governor Control
0 +50 +100 +150 +200 +250 +300
60.000
60.017
59.983
Time (seconds)
Syst
em F
requ
ency
(Hz) Governor
Deadband
Governor Deadband
Resources provide proportional response
Resources provide proportional response
Module 3
IRR Forecasting
46
• IRR Hourly Forecasting
• Wind Generation
• Photovoltaic Generation
• IRR Ramp Forecasting
Topics in this module ...
Module Topics
IRR Hourly Forecasting
48
Combination of QSE, Vendor, and ERCOT processes
Wind Generation Forecasting
Resource Site Data
Vendor Forecasting
Process(Proprietary)
Wind Generation Forecasts
49
QSE must provide site data for each WGR
Resource Site Data
Resource Site Data
Met Tower Data
Resource Telemetry
Outages
ICCP HandbookReported through
ICCP Telemetry
Details in ERCOT ICCP Handbook
Reported through Outage Scheduler
http://www.ercot.com/services/mdt/userguides
50
QSE must provide site data for each WGR
Meteorological Tower Data
Resource Site Data
Resource Telemetry
Outages
Met Tower Data
Site meteorological data
• Wind Speed
• Wind Direction
• Temperature
• Barometric Pressure
. . . updated every 10 seconds
51
QSE must provide site data for each WGR
Resource Telemetry
Resource Site Data
Resource Telemetry
Outages
Met Tower Data
Resource operational data• Resource Status
• Power Output (MW & MVAR)
• High Sustained Limit (HSL)
• Number of Turbines Online
• Number of Turbines Offline
• Number of Turbines Unknown
. . . updated every 2-10 seconds
52
QSE must provide site data for each WGR
Outages
Resource Site Data
Resource Telemetry
Outages
Met Tower Data
Resource availability data• Outage – A Resource that has
been removed from service
• Forced Derate – A portion of a Resource that has been removed from service
• 10 MW or 5% of rating*
• Must be reported if expected to last more than 48 hours
*Seasonal Net Max Sustainable Rating
53
Vendor process uses multiple forecasting models
Vendor Forecasting Process
ResourceSite Data
Forecasting Process
Plant Output Model
Statistical Models
Atmospheric Physics Models
Met Tower Data
Resource Telemetry
Outages
54
Vendor Forecasting Process
Atmospheric Physics Models
Forecasting Process
Plant Output Models
Statistical Models
Atmospheric Physics Models
Forecasting Process
Plant Output Models
Statistical Models
Atmospheric Physics Models
Suite of physical weather models
• Consume regional weather data from National Weather Service and other sources
• Produce an ensemble of weather forecasts for each region
55
Vendor Forecasting Process
Statistical Models
Forecasting Process
Plant Output Models
Statistical Models
Atmospheric Physics Models
Statistical Models
Suite of statistical models
• Incorporate QSE Met Tower Data
• Refine regional forecasts
• Accommodate local topography and conditions
• Incorporate initial conditions
• Produce an ensemble of wind speed forecasts around each Wind Generation Resource
56
Vendor Forecasting Process
Plant Output Models
Forecasting Process
Plant Output Models
Statistical Models
Atmospheric Physics Models
Plant Output Models
A model for each WGR
• Translates wind speed forecasts into wind power forecasts
• Uses manufacturer’s power curves for new plants
• Builds plant-specific power curve over time
• Met Tower Data
• Resource Telemetry Data
57
Where are we now?
From Models to Forecast
Forecasting Process
Plant Output Models
Statistical Models
Atmospheric Physics Models
At this point:
• We have an ensemble of forecasts for each WGR
• We need hourly forecasts:• For each WGR• For each ERCOT Region• For ERCOT system
. . . and all these forecasts must be consistent
58
Ensemble of hourly forecasts
Total ERCOT Wind Power Forecast
0
2000
4000
6000
8000
10000
12000
14000
1 3 5 7 9 11 13 15 17 19 21 23
MW
Hour
Summed from individual WGR forecasts
59
Protocols specify two statistical values
Using the Total ERCOT Wind Power Forecast
0
2000
4000
6000
8000
10000
12000
14000
1 3 5 7 9 11 13 15 17 19 21 23
MW
Hour
0
2000
4000
6000
8000
10000
12000
14000
1 3 5 7 9 11 13 15 17 19 21 23
MW
Hour
50% Probability of Exceedance (POE)80% Probability of Exceedance (POE)
60
Created from Total ERCOT Wind Power Forecast
Hourly Individual WGR Forecasts
Short-Term Wind Power Forecast• Allocated proportionally from 50% POE
• Rolling 168 hour forecast for each WGR
• Used in reliability studies
WGR Production Potential• Allocated proportionally from 80% POE
• Rolling 168 hour forecast for each WGR
• Used in financial settlements
61
WGR Forecasting Summary
Wind Generation Forecasting
Resource Site Data
Forecasting Process
Wind Forecasts
Plant Output Models
Statistical Models
Atmospheric Physics Models
Met Tower Data
Resource Telemetry
Outages
62
PVGR Forecasting is very similar
Solar Generation Forecasting
Resource Site Data
Forecasting Process
PhotoVoltaic Forecasts
Plant Output Models
Statistical Models
Atmospheric Physics Models
Met Tower Data
Resource Telemetry
Outages
63
QSE must provide site data for each PVGR
Meteorological Tower Data
Resource Site Data
Resource Telemetry
Outages
Met Tower Data
Site meteorological data• Wind Speed
• Wind Direction
• Temperature
• Barometric Pressure
• Back Panel Temperature
• Plane of Array Irradiance
. . . updated every 10 seconds
64
QSE must provide site data for each PVGR
Resource Telemetry
Resource Site Data
Resource Telemetry
Outages
Met Tower Data
Resource operational data• Resource Status
• Power Output (MW & MVAR)
• High Sustained Limit (HSL)
• Number of Inverters Online
• Number of Inverters Offline
• Number of Inverters Unknown
. . . updated every 2-10 seconds
65
Ensemble of hourly forecasts
Total ERCOT PhotoVoltaic Power Forecast
0
2000
4000
6000
8000
10000
12000
14000
1 3 5 7 9 11 13 15 17 19 21 23
MW
Hour
0
2000
4000
6000
8000
10000
12000
14000
1 3 5 7 9 11 13 15 17 19 21 23
MW
Hour
50% Probability of Exceedance (POE)80% Probability of Exceedance (POE)
66
Created from Total ERCOT PhotoVoltaic Power Forecast
Hourly Individual PVGR Forecasts
Short-Term PhotoVoltaic Power Forecast• Allocated proportionally from 50% POE
• Rolling 168 Hour forecast for each PVGR
• Used in reliability studies
PVGR Production Potential• Allocated proportionally from 80% POE
• Rolling 168 Hour forecast for each PVGR
• Used in financial settlements
67
WGR Dusty Mesa has just entered commercial operation
Class Discussion
IRR Hourly Forecasting Process
Resource Site Data
Met Tower Data
Resource Telemetry
Outages
1. What are the impacts if the telemetered MW Power Output is consistently low?
2. What are the impacts if the telemetered output is accurate, but the wind speed data is consistently low?
68
Posted on MIS Hourly
Publishing of Forecast Data
• Total WGR Forecasts• Regional WGR Forecasts• Total PVGR Forecasts• Regional PVGR Forecasts
• Individual WGR Forecasts• Individual PVGR Forecasts
IRR Ramp Forecasting
70
• Assesses risk of large increase in Net Load
• Estimates adequacy of scheduled Generation and Reserves to manage risk
Capacity Available Tool (CAT)
IRR Ramp Forecasting
Load
Wind
MW
Hour
CAT study window is six hours
71
• Retrieves expected Generation schedules from COPs
• Considers historical forecast uncertainties
• Wind
• Load
ERCOT Operators run CAT on demand
Capacity Available Tool (CAT) Functionality
72
• Deploying Non-Spin Reserve
• Procuring additional Non-Spin Reserve
• Committing additional Resources through RUC
ERCOT may take action to mitigate ramping risk
Capacity Available Tool (CAT) Results
30 MinReliability
UnitCommitment
Current Operating Plans
Load Forecast
Three-Part Supply Offers
Module 4
IRRs in Market and System Operations
74
• Preparing for Real-Time Operations
• IRRs during Real-Time Operations
• Dispatch Scenarios
Topics in this module ...
Module Topics
Preparing for Real-Time Operations
76
Preparing for Real-Time Operations
ReportTrades
Submit Energy Offer Curves
Update Current Operating Plan
77
• Should span operational range of the Resource
• Priced between -$250/MWh and SWCAP
• May be submitted or updated until the end of the Adjustment Period
Energy Offer Curves for IRRs
Submit Energy Offer Curves
Energy Offer Curve
$ / M
Wh
MW0
78
Preparing for Real-Time Operations
ReportTrades
Submit Energy Offer Curves
Update Current Operating Plan
79
QSEs may have Trades involving IRRs
Report Trades
Bilateral Trades
• Financial transactions between QSEs
• Transfer financial responsibility
Types
• Capacity• Energy• Ancillary Service
80
Trade Submittal Criteria
Information Needed Energy Trade Capacity Trade
Buying QSE
Selling QSE
Settlement Point:
MW quantity for each Settlement Interval 15 minute Hourly
Deadline for Submission
1430, Day after Operating Day
End of Adjustment Period
81
Trades do not “exist” until both QSEs agree
• One QSE reports the trade
• The other QSE confirms the trade
Once confirmed, either QSE may reject a Trade if the deadline for doing so has not passed.
Buyer and Seller must confirm Trades
Trade Confirmation
82
Energy Trade
• Energy supply/obligation in Real-Time
• Capacity supply/obligation in subsequent RUC
Capacity Trade
• No Energy supply/obligation in Real-Time
• Capacity supply/obligation in subsequent RUC
Energy and Capacity Trades have only Financial Impacts
Trade Impacts
83
Preparing for Real-Time Operations
ReportTrades
Submit Energy Offer Curves
Update Current Operating Plan
84
• COP reflects expected status and capabilities for each hour
• May be updated until the end of the Adjustment Period
• Must be updated within 60 minutes ofany event that impacts status or capabilities
QSE must maintain a Current Operating Plan (COP) for each Resource
Update Current Operating Plan
85
• Which Resources are planned to run
• How much capacity each Resource contributes
Reliability Unit Commitment (RUC) Process
Where is the Current Operating Plan Used?
ReliabilityUnit
Commitment
Current Operating Plans
Load Forecast
Resource Commitments
Resource DecommitmentsThree-Part
Supply Offers
86
• ON: QSE has committed to run the Resource
• OFF: Resource is offline but available for RUC commitment
• OUT: Resource is not available
Typical COP Statuses for IRRs
Current Operating Plan Status
87
• ERCOT updates COP HSL to the Short-Term Wind Power Forecast (STWPPF) for first 168 hours
• QSE may override to a lesser value
Photovoltaic Generation Resource (PVGR):
• ERCOT updates COP HSL to the Short-Term Photovoltaic Power Forecast (STPPF) for first 168 hours
• QSE may override to a lesser value
Wind-Powered Generation Resource (WGR):
Current Operating Plan Capabilities
IRRs During Real-Time Operations
89
• Manage reliability
• Resolve Transmission Constraints
• Match generation with demand
• Operate the system at least cost
Goals of SCED
Security Constrained Economic Dispatch (SCED)
SCED dispatches all available Resources in a way that
achieves these goalsSCED
90
SCED requires multiple inputs
Real-Time Dispatch
Security-ConstrainedEconomic Dispatch
Telemetry
Offers
NetworkOperations
Model
Contingencies
Real-Time Network Security Analysis
Pricing
Dispatch Instructions
91
Security Analysis provides Transmission Constraints
Real-Time Dispatch
Security-ConstrainedEconomic Dispatch
Real-Time Network Security Analysis
Telemetry
Offers
Pricing
Dispatch Instructions
NetworkOperations
Model
ContingenciesReal-Time Dispatch
Security-ConstrainedEconomic Dispatch
Constraints & Shift Factors
92
Generation-to-be-Dispatched is the projected demand
Real-Time Dispatch
Security-ConstrainedEconomic Dispatch
Telemetry
Offers
Pricing
Dispatch Instructions
NetworkOperations
Model
Contingencies
Generation to be Dispatched
Constraints & Shift Factors
93
Resource Limit Calculator determines Dispatch Limits
Real-Time Dispatch
Security-ConstrainedEconomic Dispatch
Telemetry
Offers
Pricing
Dispatch Instructions
NetworkOperations
Model
Contingencies
Constraints & Shift Factors
Resource Limit Calculator
Generation to be Dispatched
94
QSE Telemetry
• High Sustained Limit (HSL)
• Low Sustained Limit (LSL)
• Power Output
• Ramp Rates
Resource Limit Calculator
• High Dispatch Limit (HDL)
• Low Dispatch Limit (LDL)
Resource Dispatch Limits
PowerOutput
Base PointRegion
HDL
LDL
LSL
HSL
PowerOutput
5 minutes
Resource Capacity
95
• Nameplate rating
• Max output under ideal conditions
High Sustained Limit is …
• Current net output capability
• Based on current conditions
• Wind / Irradiance
• Turbines / Inverters online
High Sustained Limit is not …
HSL Expectations for IRRs
96
Resource Offers provide cost information to SCED
Real-Time Dispatch
Security-ConstrainedEconomic Dispatch
Telemetry
Offers
Pricing
Dispatch Instructions
NetworkOperations
Model
Contingencies
Constraints & Shift Factors
Resource Limit Calculator
Generation to be Dispatched
97
Pricing and Dispatch Instructions
Telemetry
NetworkOperations
Model
ContingenciesReal-Time Dispatch
Security-ConstrainedEconomic Dispatch
Offers
Pricing
Dispatch Instructions
Real-Time Network Security Analysis
Locational MarginalPrices
Resource Base Points
98
1. Dispatch to manage reliability
2. Operate the system at the least cost
Goals of IRRs
1. Dispatch to follow energy supply
2. Operate at max capability
Goals of SCED
Competing Goals?
Are IRR’s goals competing with SCED’s goals?
99
Fitting a square peg into a round hole?Class Discussion
Reconciling the Goals of SCED and IRRs
High Sustained Limit should reflect current net output capability
Give the IRR a really low price
1. How does a QSE tell SCED how much the IRR has to offer?
2. How can a QSE make SCED take everything the IRR has to offer?
Dispatch Scenarios
101
Real Time Dispatch of IRRsScenarios
Dispatch Scenarios
1. IRR with Energy Offer Curve
2. Curtailed IRR with Energy Offer Curve
3. IRR is released from curtailment
102
IRR is available for dispatch and not impacted by any binding constraints
Scenario 1
IRR with Energy Offer Curve
Energy Offer Curve
$ / MWh
MW0
• IRR runs at HSL
• IRR is a “Price-Taker”
• Base Point follows HSL
HSL
BP
103
IRR has positive shift factor on a binding constraint and must be curtailed
Scenario 2
Curtailed IRR with Energy Offer Curve
Energy Offer Curve
$ / MWh
MW0
• Base Point is less than HSL
• IRR Energy Offer Curve sets LMP
• IRR must comply with Base Point
HSL
BPBP
104
IRR has positive shift factor on a binding constraint and must be curtailed
Scenario 2
Dispatch Limits when IRR is curtailed
• SCED can move IRR from full output to any lower output in five minutes
• IRR must limit ramping to 20% of nameplate per minute
While curtailed, HSL should still represent current net output capability of the IRR
PowerOutput
LDL(LSL)
HSL
5 minutes
105
IRR has been curtailed because of a constraint. Curtailment is now lifted.
Scenario 3
IRR is Released From Curtailment
Energy Offer Curve
$ / MWh
MW0
• IRR becomes a “Price Taker” once again
• SCED will set Base Point to HSL again
BP
HSL
BP
106
IRR has been curtailed because of a constraint. Curtailment is now lifted.
Scenario 3
Dispatch Limits when IRR is Released From Curtailment
• SCED can move IRR from curtailed output to full output in five minutes
• IRR must limit ramping to 20% of nameplate per minute
LSL
HDL(HSL)
5 minutes
PowerOutput
Module 5
Financial Settlements of IRRs
108
• Real-Time Energy Imbalance
• RUC Capacity Short Charge
• Base Point Deviation Charge
Topics in this module ...
Module Topics
Real-Time Energy Imbalance
110
Real-Time Energy Imbalance at a Resource Node:
Real-Time Energy Imbalance
+
DAM Energy Purchases+
Trade Energy Purchases
DAM Energy Sales+
Trade Energy SalesRTSPP*
RTRMPR*
(-1)
(-1)
–
Metered Generation
111
At a Resource Node,
Real-Time Settlement Point Price
Time-Weighted Average LMPs
RTSPP Real-Time Settlement Point PriceRTRSVPOR Real-Time Reserve Price for On-Line ReservesRTRDP Real-Time On-Line Reliability Deployment Price
RTSPP = RTRSVPOR + RTRDP +
RTSPP is used to settle financial transactions
112
At a Resource Node,
Real-Time Resource Meter Price
(Base-Point * Time)Weighted Average LMPs
RTRMPR Real-Time Resource Meter PriceRTRSVPOR Real-Time Reserve Price for On-Line ReservesRTRDP Real-Time On-Line Reliability Deployment Price
RTRMPR = RTRSVPOR + RTRDP +
RTRMPR is used to settle physical energy production
113
Real Time Energy ImbalanceScenarios
Financial Settlement Scenarios
1. QSE with IRR in Real-Time2. QSE with IRR and Energy Trades
114
QSE has an IRR, Solaris VentumScenario 1
Scenario Data
• 100 MW nameplate rating• On-line continuously in Real-Time• During Interval 1515
• Produces 10 MWh• RTSPP = $30.00• RTRMPR = $30.02
115
Real-Time Energy Imbalance for Interval 1515:
Scenario 1
Simplifying the equation
+
DAM Energy Purchases+
Trade Energy Purchases
DAM Energy Sales+
Trade Energy SalesRTSPP*
RTRMPR*
(-1)
(-1)
–
Metered Generation
DAM Energy Sales+
Trade Energy SalesRTSPP*(-1) RTRMPR*Metered
Generation –*
Which simplifies and re-arranges to . . .
116
Real-Time Energy Imbalance for Interval 1515:
Scenario 1
Calculation
$30.02/MWh10 MWh(-1) –* = –$300.20
DAM Energy Sales+
Trade Energy SalesRTSPP*(-1) RTRMPR*Metered
Generation –*
* $30/MWh0 MWh *
117
QSE Schedules Energy Trades on their IRR, Solaris Ventum
Scenario 2
Scenario Data
• 100 MW nameplate rating• On-line continuously in Real-Time• Trade Energy Sale of 40MW during
Hour 1600• During Interval 1515
• Produces 10 MWh• RTSPP = $30.00• RTRMPR = $30.02
118
• Energy Trades are reported as hourly MWs
• Real-Time is settled as 15-minute MWhs
Trades in Real-Time Energy Settlements
Trade Conversions
Trades must be multiplied by ¼ hour
0715073007450800
0815083008450900
Hour 0800 Hour 0900
119
Real-Time Energy Imbalance for Interval 1515:
Scenario 2
Calculation
$30.02/MWh10 MWh(-1) –* = –$0.20
DAM Energy Sales+
Trade Energy SalesRTSPP*(-1) RTRMPR*Metered
Generation –*
* $30/MWh10 MWh *
RUC Capacity Short Charge
121
If ERCOT commits a Resource through RUC
• ERCOT provides QSE with a payment guarantee
• May provide “Make-Whole Payment”
Cost recovery
• QSEs are responsible for capacity
• QSEs with capacity shortfalls paythe RUC Capacity Short Charge
Reliability Unit Commitment (RUC) Costs
122
• Adjusted Metered Load
• Capacity Trades where QSE is the seller
• Energy Trades where QSE is the seller
• Cleared DAM Energy Offers
Transactions that create a capacity obligation
Capacity Obligations
Capacity required to meet QSE
Obligations
123
• Commitment of the QSE’s Resources
• Capacity Trades where the QSE is the buyer
• Energy Trades where the QSE is the buyer
• Cleared DAM Energy Bids
Transactions that create a capacity supply
Capacity Supplies
Capacity arranged by
QSE
124
Capacity arranged by
QSE
Capacity required to meet QSE ObligationsCapacity
arranged by QSE
Capacity required to meet QSE Obligations
Capacity Shortfalls captured through snapshots
RUC Capacity Short Charge
QSE Shortfall
RUC (DRUC / HRUC) Adjustment Period
QSE Shortfall
• Execution of RUC• Close of Adjustment Period
Charge based on largest shortfall
125
Real Time Energy Imbalance with RUC Capacity Shortfall in Interval 1615
Scenarios
Financial Settlement Scenarios
3. QSE with WGR and Trade before RUC4. QSE with WGR and Trades before RUC
and after Operating Hour
For both Scenarios:• WGRPP = 36 MW• STWPF = 44 MW• ERCOT has RUC Make Whole
costs to recover
126
QSE Schedules Energy Trades on their WGR, Dusty Mesa
Scenario 3
Scenario Data
• Trade Energy Sale of 40 MW reported prior to any RUC commitments
• During Interval 1615• Produces 10 MWh• RTSPP = $40.03• RTRMPR = $40.00
127
Real-Time Energy Imbalance for Interval 1615:
Scenario 3
Real-Time Energy Imbalance Calculation
$40/MWh10 MWh(-1) –* = $0.30
DAM Energy Sales+
Trade Energy SalesRTSPP*(-1) RTRMPR*Metered
Generation –*
* $40.03/MWh10 MWh *
128
QSE’s Energy Imbalance Volume is zero!Scenario 3
Real-Time Energy Imbalance
Energy required to meet QSE
Obligations
Energy provided by
QSETradeEnergy
Sale
Metered Generation
129
However, QSE has a Capacity ShortfallScenario 3
RUC Capacity Short Charge
Capacity required to meet QSE
Obligations
ShortfallCapacity
arranged by QSE
TradeEnergy
Sale(40MW)
WGRPP(36MW)
QSE must pay share of RUC Make Whole costs!
130
QSE Schedules Energy Trades on their WGR, Dusty Mesa
Scenario 4
Scenario Data
• Trade Energy Sale of 36 MW reported prior to any RUC commitments
• Additional Trade Energy Sale of 4 MW reported after the Operating Hour
• During Interval 1615• Produces 10 MWh• RTSPP = $40.03• RTRMPR = $40.00
131
Real-Time Energy Imbalance for Interval 1615:
Scenario 4
Real-Time Energy Imbalance Calculation
$40/MWh10 MWh(-1) –* = $0.30
DAM Energy Sales+
Trade Energy SalesRTSPP*(-1) RTRMPR*Metered
Generation –*
* $40.03/MWh10 MWh *
132
QSE has no Capacity ShortfallScenario 4
RUC Capacity Short Charge
Capacity Required to meet QSE
Obligations
Capacity arranged by
QSE
TradeEnergy
Saleprior to RUC
(36MW)
WGRPP(36MW)
Base Point Deviation Charge
134
IRR must be Curtailed
• Curtailment Flag
IRR must be Over-Generating
• Telemetered generation
• Instructed Base Point
Wider tolerances for deviation from Base Point
Key Differences between Intermittent Renewable Resources (IRRs) & other Resources
Base Point Deviation Charge – IRRs
135
When are IRRs exposed to deviation charges?
Conditions for Base Point Deviation
IRR output within10% acceptable range
IRR output exceeds10% acceptable range
Curtailment Flag is not set No Charge No Charge
Curtailment Flag is set No Charge Charge
IRR Groups are assessed as an aggregate
136
IRR Solaris Ventum is curtailed. How is the QSE settled?
Scenario 5
Financial Settlement Scenario
Energy Produced
IntermittentRenewableResource
AverageBasePoint
AverageOutput
10%ToleranceCharged in Base Point DeviationPrice: Max ($20, RTSPP)
Paid in Real-Time Energy ImbalancePrice: RTRMPR??
Module 6
MIS Reports for IRRs
138
• Available IRR Reports on MIS
• Details of IRR Reports
• Where to find IRR Reports
Topics in this module ...
Module Topics
139
Available IRR Reports on MIS
MIS IRR Reports
140
Wind Power Forecasts
System and Regional Totals
STWPF
WGRPP
COP HSLs
Posted every hour
Includes• Previous 48 hrs• Future 168 hrs
141
Wind Power Actuals
System and Regional Totals
5 Minute
Hourly summary posted every 5 min
Hourly
48 hour summary posted every hour
142
Wind Integration Report
Daily Values
Record Values
Wind vs. Load Comparisons
Output vs. Installed Capacity
Posted daily for previous day
143
Daily Values
Current Daily Values:
Peak Load 40,830 MWPeak Load Hour (HE) 20Wind at Peak Load Hour 3,195 MW
Max Wind 14,569 MWMax Wind Time 00:00Penetration at Max Wind Time 45.83%
Max Wind Penetration 46.53%Max Wind Penetration Time 00:30Wind Generation at Max Wind Penetration Time 14,333 MW
ERCOT Grid OperationsWind Integration Report : 03/05/2018
144
Record Values
All Time Record Values:
Record Wind Generation 17,542 MWRecord Wind Generation Time 02/19/2018 22:05Penetration at Record Wind Generation Time 46.86%
Record Wind Penetration 54.22%Record Wind Penetration Time 10/27/2017 04:00Wind Generation at Record Wind Penetration 15,408 MW
ERCOT Grid OperationsWind Integration Report : 03/05/2018
145
Wind vs. Load Comparisons
Actual Wind Output as a Percentage of the ERCOT Load03/05/2018
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22 23 00
(Win
d O
utpu
t/Lo
ad)%
Time
Actual Integrated Wind Output Actual Load
146
Output vs. Installed Capacity
Actual Wind Output as a Percentage of the Total Installed Wind Capacity03/05/2018
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 16 17 18 19 20 21 22 23 00
(Win
d O
utpu
t/In
stal
led
Win
d Ca
paci
ty)%
Time
Actual Integrated Wind Output Total WGR Installed Capacity
147
Available IRR Reports on MIS
MIS IRR Reports
148
Solar Power Forecasts
System and Regional Totals
STPPF
PVGRPP
COP HSLs
Posted every hour
Includes• Previous 48 hrs• Future 168 hrs
149
Solar Power Actuals
System and Regional Totals
5 Minute
Hourly summary posted every 5 min
Hourly
48 hour summary posted every hour
150
IRR Forecast Reports on MIS Public
151
IRR Actual Output Reports on MIS Public
152
• Differentiate between IRRs and other generation technologies in ERCOT
• Identify the unique telemetry requirements of IRRs
• Describe the operational requirements for IRRs
• Summarize the IRR forecasting process
• Summarize the dispatch process for IRRs
• Describe a few Settlement impacts for IRRs
You should now be able to …
Course Summary
153
ERCOT Protocolshttp://www.ercot.com/mktrules/nprotocols/
ERCOT Traininghttp://www.ercot.com/services/training/
ERCOT Account Management [email protected]
ERCOT Market Education [email protected]
Accessing additional information
154
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