2 nd stakeholder update: locational capacity demand curves in iso-ne
DESCRIPTION
2 nd Stakeholder Update: Locational Capacity Demand Curves in ISO-NE. Samuel A. Newell Kathleen Spees Ben Housman. July 9, 2014. ISO New England Markets Committee. Contents. Introduction Import-Constrained Zones Export-Constrained Zone Next Steps Appendix. - PowerPoint PPT PresentationTRANSCRIPT
Copyright © 2014 The Brattle Group, Inc.
PREPARED FOR
PREPARED BY
2nd Stakeholder Update:
Locational Capacity Demand Curves in ISO-NE
Samuel A. NewellKathleen SpeesBen Housman
Ju ly 9 , 2014
ISO New England Markets Committee
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Contents
▀ Introduction▀ Import-Constrained Zones▀ Export-Constrained Zone▀ Next Steps▀ Appendix
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IntroductionObjectives for Today
▀ Propose an initial candidate curve for the importing zones▀ Respond to first set of stakeholder questions on both importing and
exporting zones▀ More fully evaluate options in export-constrained zones (will wait
for stakeholder input before proposing an initial candidate curve in the next meeting)
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IntroductionIndex to Stakeholder Questions
Importing Zone Questions SlidesAre local costs and reliability outcomes reasonable? 10
How does reliability change with quantity? 11
What if true net CONE in zones is lower than in system? 12
How Does a Curve through 1.2x Net CONE at LSR Perform? 13
What are the lessons learned from PJM local curves? 14
How does PJM’s local curve compare? 15
Exporting Zone Questions Slides
How does reliability change with quantity? 20
How does the market clear in export-constrained zones? 21
Are there alternative clearing approaches? 23
How does the curve slope affect price separation? 28
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Contents
▀ Introduction▀ Import-Constrained Zones▀ Export-Constrained Zone▀ Next Steps▀ Appendix
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Import-Constrained ZonesRecap: Importing Zone Demand Curve Objectives Reliability
▀ Maintain or exceed the 0.105 LOLE (1-in-9.5) LOLE local reliability target on a long-term average basis, although LOLE in any one year may fall below that target
▀ Rarely fall into extreme reliability events where ISO-NE may be more likely to intervene, measured as max of TSA or 1-in-5 at the local level
Prices▀ Reduce susceptibility to the exercise of market power▀ Reduce price volatility impact from small variations in market conditions and
administrative parameters, including lumpy investment decisions, demand forecast changes, and transmission parameters
▀ Limit frequency of outcomes at the administrative cap▀ Rationalize prices according to the incremental reliability value (if possible)
Robustness▀ Perform well under a range of market conditions, changes in administrative
parameters, and administrative estimation errors▀ Minimize complexity and contentiousness
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Import-Constrained ZonesInitial Candidate Curve
▀ Cap: − Quantity at “minimum acceptable” reliability, defined as
MAX[1-in-5 LOLE, TSA]− Price at 1.6x Net CONE
▀ Foot: − Quantity is 1.5x the ratio above “minimum acceptable”
compared to the system curve, mathematically the quantities are:
▀ Local Net CONE: − Assumed greater than or equal to system Net CONE− Estimate local Net CONE as a separate value only if likely
to be 15% higher than system− Currently estimating <5% higher for CT, NEMA/Boston,
and SEMA/RI
NEMA Initial Candidate Curve
𝐹𝑜𝑜𝑡 𝑧𝑜𝑛𝑒=(1.5×( 𝐹𝑜𝑜𝑡𝑠𝑦𝑠𝑡𝑒𝑚𝐶𝑎𝑝 𝑠𝑦𝑠𝑡𝑒𝑚 −1))×𝐶𝑎𝑝 𝑧𝑜𝑛𝑒+𝐶𝑎𝑝 𝑧𝑜𝑛𝑒
Notes:Footsystem = 35,605Capsystem = 32,053CapNEMA = 8,059CapCT = 10,089𝐹𝑜𝑜𝑡 𝑁𝐸𝑀𝐴=(1.5×( 35,60532,053
−1))×8,059+8,059=9,399
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Import-Constrained ZonesInitial Candidate: Parameter Values by Zone
ConnecticutNEMA
Notes: MW quantities based on FCA7; prices based on a Net CONE of $11.1/kW-m. Foot quantity based on the system demand curve foot-to-cap ratio of 1.1.TTC values were 2,600 MW CT, 4,850 MW NEMA in FCA& from http://iso-ne.com/markets/othrmkts_data/fcm/doc/summary_of_icr_values%20expanded.xls
Cap to Foot
Change in Price ($/kW-m) $17.7Change in Quantity (MW) 1,340Slope ($/kW-m per 100 MW) $1.32
Cap Foot
Curve DefinitionPrice 1.6x Net CONE $0
Quantity Max of 1-in-5 LOLE or TSA
1.5x Wider than System Ratio
Corresponding Quantities in FCA7
Local + Import MW 8,059 9,399
Cap Foot
Curve DefinitionPrice 1.6 Net CONE $0
Quantity Max of 1-in-5 LOLE or TSA
1.5x Wider than System Ratio
Corresponding Quantities in FCA7
Local + Import MW 10,089 11,766
Cap to Foot
Change in Price ($/kW-m) $17.7Change in Quantity (MW) 1,677Slope ($/kW-m per 100 MW) $1.06
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Quantity Zonal Load Cost
Average Standard Deviation
Frequency at Cap
Frequency of Price
Separation
Average Excess
(Deficit) Above LSR
Standard Deviation
Frequency Below
LSR
Frequency Below
TSA
Frequency Below 1-in-5
Average LOLE
Average Customer
Costs
Average of Bottom
20%
Average of Top 20%
($/kW-m) ($/kW-m) (% of draws) (% of draws) (MW) (MW) (% of draws) (% of draws) (% of draws) (events/yr) ($mil/year) ($mil/year) ($mil/year)
NEMA/BostonVertical in Zones (System Sloped) $12.2 $4.3 23.9% 18.3% 558 404 20.0% 20.0% 6.5% 0.097 $955 $493 $1,4751x System Shape $12.2 $4.0 16.6% 25.6% 785 404 12.2% 12.2% 6.2% 0.095 $958 $497 $1,4681.5x System Shape (Initial Candidate) $12.2 $3.9 14.1% 28.1% 905 403 9.6% 9.6% 6.2% 0.095 $960 $501 $1,4622x System Shape $12.2 $3.8 11.7% 30.1% 1,050 403 6.8% 6.8% 6.2% 0.095 $962 $506 $1,457
ConnecticutVertical in Zones (System Sloped) $12.2 $4.3 24.7% 20.0% 409 469 22.2% 17.6% 10.5% 0.116 $1,228 $664 $1,8091x System Shape $12.2 $3.9 15.2% 30.1% 594 469 14.9% 11.3% 7.7% 0.107 $1,233 $699 $1,7661.5x System Shape (Initial Candidate) $12.2 $3.7 11.3% 32.7% 770 470 9.9% 7.0% 6.8% 0.102 $1,234 $717 $1,7402x System Shape $12.2 $3.5 8.3% 35.1% 957 470 5.8% 3.5% 6.5% 0.098 $1,237 $743 $1,715
Price
Import-Constrained ZonesInitial Candidate Curve Supports Objectives
▀ Combination of reliability and price objectives points to a range
▀ The candidate curve meets LOLE objective and exceeds TSA and 1-in-5 (drops below minimum acceptable 9.6% of the time in NEMA and 7% in Connecticut)
▀ …through a market that has much less volatility and substantially improved reliability compared to vertical curves
Connecticut
Recommended Range
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Import-Constrained ZonesAre Local Costs and Reliability Outcomes Reasonable?
▀ Customers in import-constrained zones can expect to pay a higher level of capacity payments than customers in the system, even though reliability in an import-constrained zone is no better than the system reliability
− This differential does not reflect an uneven cost allocation for meeting system reliability needs
− Instead it reflects: (a) the greater reliability challenges faced in import-constrained zones, and (b) the higher cost of building in those locations
▀ Higher customer costs are incurred in importing zones under either a vertical or sloped demand curve, although a more right-stretched or right-shifted curve increases the cost differential (by a small amount) because it results in a greater fraction of the need being procured locally at a higher cost
▀ Reliability in importing zones is no better than system reliability by definition:− Even without TSA, import-constrained zones will always have higher LOLE than
the system, since they are vulnerable to both system-wide and local shortages− The TSA establishes a minimum local requirement for transmission security, which
may further increase costs
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NEMA CT NEMA CT1-in-x 1-in-x LOLE LOLE
LRA 1-in-9.5 1-in-9.5 0.105 0.105TSA 1-in-16.4 1-in-8 0.061 0.125Cap 1-in-16.4 1-in-8 0.061 0.125Foot 1-in-42.3 1-in-32.9 0.024 0.030
Import-Constrained ZonesHow Does Reliability Change with Quantity?
▀ LOLE is equal to 0.105 at LRA in both zones (by definition)
▀ But TSA is a different type of reliability, not included in LOLE calculation
▀ Since TSA is the binding requirement in NEMA, the LOLE is much lower there at the LSR than in CT
NEMA/Boston
Connecticut
Acronyms:TTC = Total Transfer Capability (i.e. transmission import/export limit)LSR = Local Sourcing Requirement TSA = Transmission Security AnalysisLRA = Local Resource Adequacy
Local LOLE at Key Quantities
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Import-Constrained ZonesWhat if True Net CONE in Zones is Lower than in System?
▀ We recommend estimating a separate local Net CONE only if it is expected to be ≥ 15% higher than system Net CONE (no separate estimate if it’s lower)
▀ But what would happen if estimated Net CONE is lower in the importing zones than in system, but we model the zone as having Net CONE equal to system? We see two possible cases:− Case 1: Low Net CONE is an Underestimate. It could be that estimated
local net CONE is under-estimated, in which case setting the local curve based on the higher system Net CONE would protect against local shortages
− Case 2: Low Net CONE Attracts Excess Local Supply. If local Net CONE truly is lower than system, then suppliers will see this low-cost opportunity to develop new capacity. In this case, all supply needed to meet the system requirement will be sited in the local zone and the import constraint will not bind (so the zone demand curve will have no effect).
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Quantity Zonal Load Cost
Average Standard Deviation
Frequency at Cap
Frequency of Price
Separation
Average Excess
(Deficit) Above LSR
Standard Deviation
Frequency Below
LSR
Frequency Below
TSA
Frequency Below 1-in-5
Average LOLE
Average Customer
Costs
Average of Bottom
20%
Average of Top 20%
($/kW-m) ($/kW-m) (% of draws) (% of draws) (MW) (MW) (% of draws) (% of draws) (% of draws) (events/yr) ($mil/year) ($mil/year) ($mil/year)
NEMA/BostonInitial Candidate Curve (1.5x System) $12.2 $3.9 14.1% 28.1% 905 403 9.6% 9.6% 6.2% 0.095 $960 $501 $1,462LSR at 1.2x Net CONE $12.2 $4.0 15.6% 24.3% 569 404 19.7% 19.7% 6.3% 0.097 $955 $499 $1,459
ConnecticutInitial Candidate Curve (1.5x System) $12.2 $3.7 11.3% 32.7% 770 470 9.9% 7.0% 6.8% 0.102 $1,234 $717 $1,740LSR at 1.2x Net CONE $12.2 $3.9 15.0% 29.5% 432 469 21.4% 17.0% 10.3% 0.115 $1,230 $700 $1,759
Price
Import-Constrained ZonesHow Does a Curve through 1.2x Net CONE at LSR Perform?
Notes: Base case assumes true Net CONE in NEMA/Boston and Connecticut is 10% higher than system.Zonal load costs reflect capacity procurement costs paid by customers in each zone, assuming all zonal CTRs are awarded to local customers.
Connecticut▀ Curve shape same as system:− Cap and foot quantities are the same quantity % below and
above LSR as the system curve is relative to NICR− Slope in absolute MW terms is steeper than system− Does not account for TSA or local 1-in-5 as minimum
acceptable▀ Curve shows slightly greater price volatility, but much
poorer reliability with 17% and 20% below TSA in NEMA and CT respectively
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Import-Constrained ZonesWhat are the Lessons Learned from PJM Local Curves? Many Lessons Learned Also Apply in ISO-NE:
▀ Shocks to supply and demand are greater relative to zone size, creating more price volatility and reliability concerns
▀ Percentage-based demand curves become very steep in small zones (approaching vertical), leading to higher price volatility (mostly manifesting as price spikes because downside volatility is mitigated by parent zone curves)
▀ Small zones with little development activity and few historical data points are more susceptible to administrative Net CONE errors
Some Do Not Apply (at Least Not Presently):▀ In multi-level nested zone structure, the most import-constrained zones
are most at risk from a reliability perspective ▀ Transmission parameters (equivalent to ISO-NE’s TTC) in the capacity
market are varying greatly each year, introducing greater price volatility and reliability concerns in the most import-dependent locations
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Quantity Zonal Load Cost
Average Standard Deviation
Frequency at Cap
Frequency of Price
Separation
Average Excess
(Deficit) Above LSR
Standard Deviation
Frequency Below
LSR
Frequency Below
TSA
Frequency Below 1-in-5
Average LOLE
Average Customer
Costs
Average of Bottom
20%
Average of Top 20%
($/kW-m) ($/kW-m) (% of draws) (% of draws) (MW) (MW) (% of draws) (% of draws) (% of draws) (events/yr) ($mil/year) ($mil/year) ($mil/year)
NEMA/BostonInitial Candidate Curve (1.5x System) $12.2 $3.9 14.1% 28.1% 905 403 9.6% 9.6% 6.2% 0.095 $960 $501 $1,462PJM VRR $12.2 $3.9 6.2% 25.8% 456 403 25.8% 25.8% 7.2% 0.099 $952 $497 $1,440
ConnecticutInitial Candidate Curve (1.5x System) $12.2 $3.7 11.3% 32.7% 770 470 9.9% 7.0% 6.8% 0.102 $1,234 $717 $1,740PJM VRR $12.2 $3.8 6.2% 28.7% 329 469 26.7% 20.8% 12.0% 0.122 $1,225 $691 $1,713
Price
Import-Constrained ZonesHow Does PJM’s Local Curve Compare?
Notes: Base case assumes true Net CONE in NEMA/Boston and Connecticut is 10% higher than system.Zonal load costs reflect capacity procurement costs paid by customers in each zone, assuming all zonal CTRs are awarded to local customers.
ConnecticutPJM Local VRR Curve (As Applied to ISO-NE)
▀ PJM applies the same curve to the zones as to the system (as a percentage of the system or local reliability requirement)
▀ Note: PJM has proposed to adopt a flatter, convex, right-shifted shape which is currently under stakeholder review
Performance ▀ Similar price volatility and fewer events at the cap▀ Portion of curve below TSA introduces more severe reliability
events, with 21% and 26% frequency below TSA in CT and NEMA respectively
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Import-Constrained ZonesSummary Comparison of Curves (Connecticut)
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Quantity Zonal Load Cost
Average Standard Deviation
Frequency at Cap
Frequency of Price
Separation
Average Excess
(Deficit) Above LSR
Standard Deviation
Frequency Below
LSR
Frequency Below
TSA
Frequency Below 1-in-5
Average LOLE
Average Customer
Costs
Average of Bottom
20%
Average of Top 20%
($/kW-m) ($/kW-m) (% of draws) (% of draws) (MW) (MW) (% of draws) (% of draws) (% of draws) (events/yr) ($mil/year) ($mil/year) ($mil/year)
NEMA/BostonInitial Candidate Curve (1.5x System) $12.2 $3.9 14.1% 28.1% 905 403 9.6% 9.6% 6.2% 0.095 $960 $501 $1,4621x System Shape $12.2 $4.0 16.6% 25.6% 785 404 12.2% 12.2% 6.2% 0.095 $958 $497 $1,4682x System Shape $12.2 $3.8 11.7% 30.1% 1050 403 6.8% 6.8% 6.2% 0.095 $962 $506 $1,457Vertical in Zones and System $12.2 $6.3 54.2% 10.7% 502 398 21.7% 21.7% 15.2% 0.145 $937 $275 $1,639Vertical in Zones (System Sloped) $12.2 $4.3 23.9% 18.3% 558 404 20.0% 20.0% 6.5% 0.097 $955 $493 $1,475Flatter, Curves at 1,500 Width $12.2 $3.8 13.0% 27.4% 976 403 8.2% 8.2% 6.2% 0.095 $962 $505 $1,461Steeper, Cap at 1.75x in Zones $12.2 $4.3 9.5% 23.2% 911 404 9.5% 9.5% 6.2% 0.094 $959 $496 $1,498PJM VRR $12.2 $3.9 6.2% 25.8% 456 403 25.8% 25.8% 7.2% 0.099 $952 $497 $1,440LSR at 1.2x Net CONE $12.2 $4.0 15.6% 24.3% 569 404 19.7% 19.7% 6.3% 0.097 $955 $499 $1,459
ConnecticutInitial Candidate Curve (1.5x System) $12.2 $3.7 11.3% 32.7% 770 470 9.9% 7.0% 6.8% 0.102 $1,234 $717 $1,7401x System Shape $12.2 $3.9 15.2% 30.1% 594 469 14.9% 11.3% 7.7% 0.107 $1,233 $699 $1,7662x System Shape $12.2 $3.5 8.3% 35.1% 957 470 5.8% 3.5% 6.5% 0.098 $1,237 $743 $1,715Vertical in Zones and System $12.2 $6.2 53.0% 12.6% 345 443 22.9% 18.2% 18.6% 0.154 $1,203 $384 $1,848Vertical in Zones (System Sloped) $12.2 $4.3 24.7% 20.0% 409 469 22.2% 17.6% 10.5% 0.116 $1,228 $664 $1,809Flatter, Curves at 1,500 Width $12.2 $3.7 12.3% 30.6% 728 470 11.0% 7.9% 6.9% 0.104 $1,233 $714 $1,747Steeper, Cap at 1.75x in Zones $12.2 $4.1 7.9% 26.7% 721 469 11.1% 7.9% 6.9% 0.103 $1,232 $688 $1,833PJM VRR $12.2 $3.8 6.2% 28.7% 329 469 26.7% 20.8% 12.0% 0.122 $1,225 $691 $1,713LSR at 1.2x Net CONE $12.2 $3.9 15.0% 29.5% 432 469 21.4% 17.0% 10.3% 0.115 $1,230 $700 $1,759
Price
Import-Constrained ZonesSummary Comparison of Curves
Notes: Base case assumes true Net CONE in NEMA/Boston and Connecticut is 10% higher than system.Zonal load costs reflect capacity procurement costs paid by customers in each zone, assuming all zonal CTRs are awarded to local customers.
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Contents
▀ Introduction▀ Import-Constrained Zones▀ Export-Constrained Zone▀ Next Steps▀ Appendix
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Export-Constrained ZoneExporting Zone Demand Curve Objectives Reliability
▀ Maintain or exceed the 0.1 LOLE (1-in-10) system reliability target on a long-term average basis, although LOLE in any one year may fall below that target (less likely to be a limiting factor in an export-constrained area)
Prices▀ Rationalize prices according to the incremental reliability value (if possible)▀ Reduce susceptibility to the exercise of market power (buyer side)▀ Reduce price volatility impact from small variations in market conditions and
administrative parameters, including lumpy investment decisions, demand forecast changes, and transmission parameters
Robustness▀ Perform well under a range of market conditions, changes in administrative
parameters, and administrative estimation errors▀ Minimize complexity and contentiousness
Exporting zones are unlike importing zones and introduce different complexities that have to be resolved with a balance among these objectives.
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Export-Constrained ZoneHow Does Reliability Change with Quantity?
▀ Beginning with the system LOLE run used to calculate MCL, add or subtract MW from Maine (keeping rest of system supply constant)
▀ At Maine supply quantities substantially below MCL, there is no difference in reliability outcomes or reliability value of supply between Maine and System
▀ Starting about 500 MW below MCL, the contribution of Maine supply to meeting system 0.1 days/ year LOLE criteria diminishes as the export constraint can be expected to bind more frequently
Maine
Reliability at Points on CurveCap MCL Foot
Same as System Curve Quantity in Maine (MW) 3,606 3,709 4,006Maine LOLE (Ev/Yr) 0.008 0.007 0.005Rest of System LOLE (Ev/Yr) 0.107 0.105 0.100
2x Wider CurveQuantity in Maine (MW) 3,503 3,709 4,302Maine LOLE (Ev/Yr) 0.026 0.007 0.003Rest of System LOLE (Ev/Yr) 0.112 0.105 0.100
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Export-Constrained ZoneHow Does the Market Clear in Exporting Zones?
Case 1: Maine is Export-Constrained
System
Maine
Case 2: Maine Clears with System
Infeasible Blocks will not clear, as the quantity exceeds the maximum demand in Maine at high pricesFeasible Blocks
Considered for system need
Feasible Blocks From Maine
Maine PriceLower than System
System Price
Supply curve if all Maine supply could be used for system
SupplyCurve
Some lower-cost Maine supply fails to clear even though it is lower-cost. If it had cleared it would displace some system supply from elsewhere (reducing system reliability)
System
Maine
Infeasible Blocks will not clear, as the quantity exceeds the maximum demand in Maine at high pricesFeasible Blocks
Considered for system need
Feasible Blocks From Maine
Max possible Maine price is higher than
system, so Maine does not price separate
System PriceAnd Maine Price
SupplyCurve
Some feasible Maine supply does not clear at the low system price
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Export-Constrained ZoneIssue with Demand Curve and Current DCA Format▀ Simple example shows quantity uncertainty from demand curve in export-constrained
zone incompatible with descending clock auction (DCA) in its current format▀ Problem can be solved by: (a) not finalizing any zone’s price until all zones clear, (b)
vertical curve in Maine, or (c) not counting any MW from Maine toward system need in excess of MCL
Maine
Visible PortionOf Supply Curve
Supply Curve May Have Any Shape
System
Uncertain MW Available for Export to System
Possible Clearing PricesUnclear whether auctionShould close for system.ME Imports
ME Imports
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Approach1. Vertical Constraint at MCL
2. Sloped Maximum Demand Curve
3. Prorating Payments for Quantities above MCL
4. Discount MW Based on System Reliability Value
Export-Constrained ZoneAre there Alternative Clearing Approaches?
MCL
MCL
MCL
System Price
PayoutRate
MCL
System Price
PayoutRate
▀ In the following slides we describe four alternative approaches to addressing market clearing in export constrained zones
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Export-Constrained Zone: Alternative Approaches1. Vertical Constraint at MCL
Vertical Demand Curve
Curve Parameters
Maine Clearing Price and Quantity
System Price
Slope: $17.7/kW-m Cap to Foot
Cap Foot Difference
Price 1.6x Net CONE $0 $17.7
Quantity MCL MCL -
Corresponding Quantities in FCA7 (MW) 3,709 3,709 0
Approach 1: Vertical Constraint at MCLConcept • Vertical curve at MCL
• Curve design currently used in FCM
Supplier Payments
• Maine Clearing Price
Pros • Simplest • No possibility of procurement above MCL
Cons • Highest price volatility
Implementation Challenges
• None: current design
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Approach 2: Sloped Maximum Demand CurveConcept • Sloped maximum demand curve
• Defines maximum price that can be paid at each quantity
Supplier Payments
• Maine Clearing Price
Pros • Mitigates against bimodal price (modest improvement)
Cons • Degrades system reliability because local supply is treated the same as system supply (increases system LOLE by 0.002 Ev/Yr but problem would worsen with flatter curves that perform better in price volatility)
• Auction could result in no price separation even when the quantity in ME exceeds MCL
Implementation Challenges
• Inconsistent with current DCA. Possible solution: do not close any zone until all zones clear (but offers can be fixed for subsequent rounds)
• Other issues TBD by ISO-NE
Export-Constrained Zone: Alternative Approaches2. Sloped Maximum Demand Curve
Sloped Demand Curve
Curve Parameters
Maine Clearing Price and Quantity
System Price
Cap Foot Difference
Price 1.6x Net CONE $0 $17.7
Quantity -2.78% below MCL 1.1x Cap Quantity -
Corresponding Quantities in FCA7 (MW) 3,606 4,006 400
Slope: $4.4/kW-m per 100 MW
Notes: The sloped demand curve depicted above is based on the same cap-to-foot ratio as the system curve, with the same quantity percentage above and below MCL as the system relative to NICR. By coincidence, this curve passes through MCL at the system price in the example we show; however, the curve has not been designed to pass through MCL at the system price.
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Export-Constrained Zone: Alternative Approaches3. Prorating Payments for Quantities above MCL
Prorating Payments for For Quantities above MCL
Maine Clearing Price and Quantity
System PriceProrated MainePayout Rate
Approach 3: Prorating Quantities above MCLConcept • Maine can clear quantities above MCL, but no
more than MCL counts toward system need• Maine suppliers offering below prorated
payout rate would not clear
Supplier Payments
• Maine Payout Rate = (System Price * MCL) / Maine Cleared Quantity
Pros • Lowest price volatility in Maine (almost same as system)
Cons • Large potential for uneconomic over-supply in Maine
Implementation Challenges
• TBD by ISO-NE
Slope: $0.3/kW-m per 100 MW (steepest slope, assumes system clears at Net CONE)
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Export-Constrained Zone: Alternative Approaches4. Discount MW Based on System Reliability Value
Relative Reliability Curve
Maine Clearing Price and Quantity
System Price
Discounted MainePayout Rate
0%
20%
40%
60%
80%
100%
2,500 3,500 4,500
Mar
gina
l Val
ue (%
)
Local Generation (ICAP MW)
MCL
Marginal Value
0
1,000
2,000
3,000
4,000
5,000
2,500 3,500 4,500
Cum
ulati
ve V
alue
(MW
)
Local Generation (ICAP MW)
MCL
x-y line
Cumulative Value
Cumulative Reliability Value of Maine Capacity
Marginal Reliability Value (as % of System Capacity)
Approach 4: Discounted MW to Reliability ValueConcept • Discount Maine suppliers’ MW to equivalent
marginal reliability value at the system level (declines at MW > MCL)
• Makes Maine supply offers appear higher per MW compared to system MW as oversupply increases
• Cumulative MW asymptotes at MCL
Supplier Payments
• Maine Payout Rate = System Price * Marginal Reliability Value
Pros • Most economically rational• Substantially mitigates price volatility
Cons • Complex, untested
Implementation Challenges
• Inconsistent with current DCA
Slope: $2.2/kW-m per 100 MW (steepest slope, assumes system clears at Net CONE)
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$0
$5
$10
$15
$20
3,40
0
3,50
0
3,60
0
3,70
0
3,80
0
3,90
0
4,00
0
4,10
0
4,20
0
4,30
0
4,40
0
Pric
e ($
/kW
-m IC
AP)
Local ICAP MW
MCL
System Net CONE
Maine Net CONE
Export-Constrained ZoneHow Does the Curve Slope Affect Price Separation?
▀ A flatter Maine curve will:− Still result in the same average price over the
long run (based on local Net CONE, currently assumed at 10% lower than system Net CONE)
− Reduce price volatility (i.e. reduce the magnitude of any one price separation event)
− Increase the frequency of price separation to 25% (compared to 13% with a vertical curve), but result in the same average price delta across years
Maine Price Separation Schematic
More frequent (but smaller) price separation events occur with a flat curve (resulting in the same average price in both cases).
An identical supply shock causes more price separation with a steeper curve.
0 20 40 60 80 100
-$0 to -$2
-$2 to -$4
-$4 to -$6
-$6 to -$8
< -$8
Frequency (Count of 1,000 Draws)
Pric
e Se
para
tion
from
Sys
tem
($/k
W-m
)
Frequency of Price Separation by Magnitude(Maine Price minus System Price)
Vertical at MCL1x Width Curve2x Width Curve (Flattest)
2x Width curve shows 58% of price separation events within $4/kW-m of RoS price
2x Width curve shows 51% of price separation events more than $8/kW-m below RoS price
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Export-Constrained ZoneComparison of Alternative Approaches
System Price
Prorated
Sloped Maximum Demand Curve
Reliability ValueVertical
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Contents
▀ Introduction▀ Import-Constrained Zones▀ Export-Constrained Zone▀ Next Steps▀ Appendix
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Next Steps
Date Meeting or Deadline
June 10-11, 2014 MC Capacity zone demand curve concepts and candidate curves
June 20, 2014 Participants submit additional questions which Brattle will endeavor to answer at the July 8-10 MC
July 8-10, 2014 MC Answers to stakeholder questions
July 18, 2014 Participants submit additional questions which Brattle will endeavor to answer at the August 5-6 MC
Aug. 5-6, 2014 MC Answers to stakeholder questions
Aug. 8, 2014 Participants submit additional alternative zonal demand curve proposals for quantitative & qualitative analysis
Sep. 3-4, 2014 MC Results of quantitative analysis for stakeholder proposals (and ISO proposed demand curves)
▀ Please submit questions, comments, or alternative proposed curves to ISO-NE by July 18, for Brattle response in the August MC meeting
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Contents
▀ Introduction▀ Import-Constrained Zones▀ Export-Constrained Zone▀ Next Steps▀ Appendix
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Quantity Zonal Load CostAverage Standard
DeviationFrequency
at CapFrequency
of Price Separation
Average Quantity
Above (Below) MCL
Standard Deviation
System LOLE
Final Customer
Costs
Averageof Bottom
20%
Averageof Top 20%
($/kW-m) ($/kW-m) (% of draws) (% of draws) (MW) (MW) (events/yr) ($mil/year) ($mil/year) ($mil/year)
MaineInitial Candidate Curve (1.5x System) $10.0 $4.4 4.3% 13.2% (385) 152 0.093 $288 $103 $4571x System Shape $10.0 $4.4 4.3% 13.1% (385) 151 0.094 $289 $105 $4572x System Shape $10.0 $4.4 4.3% 13.5% (378) 153 0.094 $288 $101 $457Maine with Sloped Curve $10.0 $4.1 3.7% 18.6% (265) 161 0.096 $288 $122 $455Maine with Sloped Curve (2x Wider) $10.0 $3.7 3.1% 25.2% (176) 163 0.099 $288 $140 $448Vertical in Zones and System $10.0 $6.6 38.7% 11.6% (410) 187 0.145 $283 $66 $529Vertical in Zones (System Sloped) $10.0 $4.4 4.3% 13.5% (378) 153 0.094 $288 $102 $457Flatter, Curves at 1,500 Width $10.0 $4.4 4.3% 13.5% (377) 153 0.094 $288 $101 $458Steeper, Cap at 1.75x in Zones $10.0 $4.4 4.3% 13.1% (386) 151 0.093 $289 $106 $457PJM VRR $10.0 $4.0 6.6% 22.3% (320) 158 0.095 $288 $120 $447LSR at 1.2x Net CONE $10.0 $4.4 4.3% 13.5% (378) 153 0.094 $288 $102 $458
Price
AppendixMaine Simulation Results
Notes: System LOLE exceeds 0.100 in base case for 3 reasons: (1) slight difference in approach to translating system curve to zones (impact of 0.002), (2) applying a vertical curve in Maine in the base Case (impact of 0.002), and (3) change from 15% to 10% higher/lower Net CONE in zones (impact of 0.002).Base case assumes true Net CONE in NEMA/Boston and Connecticut is 10% higher than system.Zonal load costs reflect capacity procurement costs paid by customers in each zone, assuming all zonal CTRs are awarded to local customers.
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Appendix B: Detailed Local ResultsNEMA Results
▀ Avg Price: $12.2/kW-m (SD = 4.3kW-m)
▀ Avg cleared quantity +TTC as % of LSR + TTC: 107.4% (SD = 9.2%)
▀ % of draws below TSA: 20.0%▀ Avg Cost: $958 mil
▀ Avg Price: $12.2/kW-m (SD = $3.9kW-m)
▀ Avg cleared quantity +TTC as % of LSR + TTC: 111.7% (SD = 9.4%)
▀ % of draws below TSA: 9.6%▀ Avg Cost: $960 mil
Initial Candidate Curve
Vertical Curve for Zones (System Sloped)
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Appendix B: Detailed Local ResultsConnecticut Results
▀ Avg Price: $12.2/kW-m (SD = $4.3kW-m)
▀ Avg cleared quantity +TTC as % of LSR + TTC: 104.1% (SD = 5.9%)
▀ % of draws below TSA: 17.6%▀ Avg Cost: $1,233 mil
▀ Avg Price: $12.2/kW-m (SD = $3.7kW-m)
▀ Avg cleared quantity +TTC as % of LSR + TTC: 107.7% (SD = 5.9%)
▀ % of draws below TSA: 7.0%▀ Avg Cost: $1,234 mil
Initial Candidate Curve
Vertical Curve for Zones (System Sloped)
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AppendixMaine ResultsLocal Curve Vertical at MCL
▀ Avg Price: $10.0/kW-m (SD = $4.4 kW-m)
▀ Avg cleared quantity as % MCL: 90.1%
▀ % of draws above MCL: 0.0%▀ Avg Cost: $289 mil
▀ Avg Price: $10.0/kW-m (SD = $4.1 kW-m)
▀ Avg cleared quantity as % MCL: 93.4%
▀ % of draws above MCL: 22.9%▀ Avg Cost: $288 mil
Local Curve Same Shape as System Curve
Note: Assumes import-constrained curves have same sloped shape as system.