4 th Stakeholder Update: Locational Capacity Demand Curves in ISO-NE
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Transcript of 4 th Stakeholder Update: Locational Capacity Demand Curves in ISO-NE
Copyright © 2014 The Brattle Group, Inc.
PREPARED FOR
PREPARED BY
4th Stakeholder Update:
Locational Capacity Demand Curves in ISO-NE
Samuel A. NewellKathleen SpeesBen Housman
October 7 , 2014
ISO New England Markets Committee
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Contents
▀ Introduction▀ Impact of Model Updates▀ Stakeholder Questions
− Import-Constrained Zonal Demand Curves− Export-Constrained Zonal Demand Curves
▀ Summary Comparison of Zonal Demand Curves▀ Appendix
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IntroductionObjectives for Today
▀ Benchmark the impact of model updates (described in ISO-NE’s prior presentation)
▀ Provide analytical results illustrating performance of ISO-NE’s proposed locational demand curve and market clearing rules
▀ Summarize analysis of stakeholder proposed curves and respond to stakeholder questions
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IntroductionIndex to Stakeholder Questions
Importing Zone Questions Slides
NU &UI: FCA 8 Back-Cast, ISO-NE Proposed Curve, FCA 8 Cleared Supply as Price-Takers 11
NU: FCA 8 Back-Cast, ISO-NE Proposed Curve, FCA 8 Cleared Supply, Plus 600 MW plant in CT at $7/kW-m 11
NU: Cap at 1-in-5, Foot at 1-in-87 12
NESCOE: NESCOE Curve, 70% shock size, more elastic supply curve 13
CT PURA & DEEP: Proposed Curve, LOLE capped at TSA 14-16
CT PURA & DEEP: Proposed Curve, No Demand Shock 14-16
CT PURA & DEEP: Proposed Curve Shifted to LOLE at 0.105, 70% Shock Size 14-16
CT PURA & DEEP: Proposed Curve Shifted to LOLE at 0.105, LOLE capped at TSA 14-16
CT PURA & DEEP: Proposed Curve Shifted to LOLE at 0.105, No Demand Shock 14-16
CT PURA & DEEP: Cap at 1-in-5, LOLE at 0.105 14-16
CT PURA & DEEP: Cap at 1-in-5, LOLE at 0.105, LOLE Capped at TSA 14-16
CT PURA & DEEP: Cap at 1-in-5, LOLE at 0.105, LOLE Capped at TSA, No Demand Shock 14-16
UI: What Are Local Prices When LOLE is Similar to System? 17-18
Exporting Zone Questions Slides
Emera Energy: 1.5x Width 20
NESCOE: Cap at MCL, Foot at 1x Foot 21
NESCOE: Cap at MCL, Vertical to System Net CONE, Foot at 1x Foot 21
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Contents
▀ Introduction▀ Impact of Model Updates▀ Stakeholder Questions
− Import-Constrained Zonal Demand Curves− Export-Constrained Zonal Demand Curves
▀ Summary Comparison of Zonal Demand Curves▀ Appendix
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Model UpdatesDescription of Model Updates
▀ We describe and show the impacts of two simulation model changes that we have implemented to reflect ISO-NE’s requested updates (see Appendix and written stakeholder responses for more detail):
1. Updated LOLE Calculation and Reporting
2. FCM Auction Clearing Rules
▀ The updated LOLE calculation results in minor changes
▀ Adjustment to the auction clearing has more impact on results− Differences occur in approximately 1/3 of draws, when one or both
import zones price separate− Results are the same as the prior clearing model if there is no price
separation (if assuming the same supply and demand in a particular draw, i.e. with no “smart block” adjustment)
− Comparison of results for a range of zonal curves is included in appendix
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Model UpdatesImpact on System Results
▀ Updated LOLE calculation shows minimal impact (but new reported metric provides additional information)
▀ Revised clearing algorithm slightly increases price volatility and reduces reliability system-wide
▀ Effect becomes larger with increasing width of local curves and number of importing zones
System Performance Impacts of Model UpdatesISO-NE Proposed System and Local Curves (1x No TTC)
Reliability System Load Cost
AverageStandard Deviation
Frequency at Cap
Constra ined System
LOLE
Unconstra ined System
LOLE
Average Reserve Margin
Reserve Margin St. Dev.
Frequency Below NICR
Frequency Below
1-in-5 in RoP
AverageAverage of
Bottom 20%
Average ofTop20%
($/kW-m) ($/kW-m) (% of draws) (events/yr) (events/yr) (%) (%) (% of draws) (% of draws) ($mil/yr) ($mil/yr) ($mil/yr)
Prior Model $11.1 $3.7 6.3% n/a 0.097 13.5% 2.7% 30.9% 6.8% $4,523 $2,638 $6,416Updated LOLE Calculation $11.1 $3.7 6.3% 0.111 0.097 13.5% 2.7% 30.9% 7.2% $4,523 $2,638 $6,416Updated LOLE and Clearing Rules $11.1 $3.8 6.3% 0.120 0.109 12.9% 2.7% 37.2% 10.1% $4,506 $2,685 $6,428
Price
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Quantity Zonal Load Cost
Average Standard Deviation
Frequency at Cap
Frequency of Price
Separation
Average Excess
(Deficit) Above LSR
Standard Deviation
Frequency Below
LSR
Frequency Below
TSA
Frequency Below 1-in-5
Average LOLE
Average Customer
Costs
Average of Bottom
20%
Average of Top 20%
($/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/BostonPrior Model $12.2 $4.2 20.8% 20.8% 652 404 16.2% 16.2% 7.4% 0.099 $955 $494 $1,471Updated LOLE Calculation $12.2 $4.2 20.8% 20.8% 652 404 16.2% 16.2% 7.3% 0.097 $955 $494 $1,471Updated LOLE and Clearing Rules $12.2 $4.1 18.9% 16.9% 743 405 13.7% 13.7% 10.2% 0.109 $946 $497 $1,421
ConnecticutPrior Model $12.2 $4.0 16.9% 25.9% 523 469 17.8% 13.3% 9.0% 0.112 $1,228 $689 $1,774Updated LOLE Calculation $12.2 $4.0 16.9% 25.9% 523 469 17.8% 13.3% 10.4% 0.111 $1,228 $689 $1,774Updated LOLE and Clearing Rules $12.2 $3.9 15.9% 21.9% 615 469 14.1% 10.9% 13.3% 0.120 $1,221 $696 $1,739
Price
▀ Revised clearing algorithm shows slightly lower price volatility in zones▀ Reliability below target in zones, associated primarily with lower reliability
on a system basis (see prior slide)▀ But more supply is locally-sourced (reducing the contribution of LOLE from
locally-driven events)
Model UpdatesImpact on Importing Zone Results
Importing Zone Impacts of Model UpdatesISO-NE Proposed System and Local Curves (1x No TTC)
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Quantity Zonal Load CostAverage Standard
DeviationFrequency
at CapFrequency
of Price Separation
Average Quantity
Above (Below) MCL
Standard Deviation
Constrained System
LOLE
Unconstrained System
LOLE
Final Customer
Costs
Averageof Bottom
20%
Averageof Top 20%
($/kW-m) ($/kW-m) (% of draws) (% of draws) (MW) (MW) (events/yr) (events/yr) ($mil/year) ($mil/year) ($mil/year)
Prior Model $10.0 $4.1 3.8% 19.2% (263) 163 n/a 0.097 $288 $121 $455Updated LOLE Calculation $10.0 $4.1 3.8% 19.3% (263) 163 0.111 0.097 $288 $121 $455Updated LOLE and Clearing Rules $10.0 $4.1 4.0% 19.1% (267) 168 0.120 0.109 $287 $120 $457
Price
ISO-NE ProposalImpact on Exporting Zone Results
▀ Minimal changes to realized performance in Maine▀ Primary performance change is associated with impact of revised clearing
mechanics on system price and reliability results
Exporting Zone Impacts of Model UpdatesISO-NE Proposed System and Local Curves (1x Curve in Exporting Zone)
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Contents
▀ Introduction▀ Impact of Model Updates▀ Stakeholder Questions
− Import-Constrained Zonal Demand Curves− Export-Constrained Zonal Demand Curves
▀ Summary Comparison of Zonal Demand Curves▀ Appendix
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Back-Cast of FCA 8 Results
Import-Constrained ZonesNU & UI: FCA 8 Back-Cast with Proposed Curves
▀ Request to re-run FCA 8 auction results with system and local demand curves treating cleared supply as price takers
▀ No price separation occurs across zones▀ Back-cast prices would have dropped from
$15.0 to $13.9/kW-m in the presence of the system demand curve
▀ Adding a 600 MW plant would have reduced the prices to $11.9/kW-m
Assumptions
• FCA 8 demand parameters• System demand curve with Net CONE at
11.08/kW-m• ISO-NE proposed curve in zones • Case 1: FCA 8 cleared supply as price-takers• Case 2: Add a 600 MW plant at $7/kW-m in
Connecticut
Note: Cleared quantity excludes TTC.
Cleared Quantity Cleared Price MWs Above (Below) Requirement
System CT NEMA Maine System CT NEMA Maine NICR CT LSR NEMA LSR ME MCL(MW) (MW) (MW) (MW) ($/kW-m) ($/kW-m) ($/kW-m) ($/kW-m) (MW) (MW) (MW) (MW)
Actual (No Administrative Pricing) 33,702 9,191 3,821 3,755 $15.00 $15.00 $15.00 $15.00 (153) 1,872 393 (205)
Case 1: System Sloped (Zones Vertical) 33,702 9,191 3,821 3,755 $13.90 $13.90 $13.90 $13.90 (153) 1,872 393 (205)
Case 1: ISO-NE Proposed Curves 33,702 9,191 3,821 3,755 $13.90 $13.90 $13.90 $13.90 (153) 1,872 393 (205)
Case 2: ISO-NE Proposed Curves, Add 600 MW in CT 34,302 9,791 3,821 3,755 $10.99 $10.99 $10.99 $10.99 447 2,472 393 (205)
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Quantity Zonal Load Cost
Average Standard Deviation
Frequency at Cap
Frequency of Price
Separation
Average Excess
(Deficit) Above LSR
Standard Deviation
Frequency Below
LSR
Frequency Below
TSA
Frequency Below 1-in-5
Average LOLE
Average Customer
Costs
Average of Bottom
20%
Average of Top 20%
($/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/Boston
ISO-NE Proposal (1.0x No TTC) $12.2 $4.1 18.9% 16.9% 743 405 13.7% 13.7% 10.2% 0.109 $946 $497 $1,421NU: Cap at 1-in-5, Foot at 1-in-87 $12.2 $3.8 10.3% 21.4% 726 403 14.4% 14.4% 13.3% 0.125 $938 $466 $1,445
Connecticut
ISO-NE Proposal (1.0x No TTC) $12.2 $3.9 15.9% 21.9% 615 469 14.1% 10.9% 13.3% 0.120 $1,221 $696 $1,739
NU: Cap at 1-in-5, Foot at 1-in-87 $12.2 $3.7 10.3% 24.6% 1,277 471 1.6% 0.8% 13.5% 0.126 $1,226 $708 $1,695
Price
Performance
Import-Constrained ZonesNU Curve: Cap at 1-in-5, Foot at 1-in-87
▀ Concept is to define local demand curves according to the same LOLE-based definition as in system
▀ Results in flatter local curves and lower price volatility▀ However, reliability is degraded in both zones:
− Result may appear counter-intuitive, but is a consequence of implementing a wide curve in combination with updated clearing rules
− Wide local curves result in less rest-of-system procurement during price separation, therefore reduced rest-of-system reliability and increased rest-of-system price volatility
− ISO-NE clearing rules will prohibit use of a zonal curve this wide with three importing zones (demand quantity in zones could exceed system curve width)
Connecticut
Note: Curve names are labeled based on the stakeholder suggesting those curves for analysis, but do not necessarily reflect that stakeholder’s recommended approach in all cases.
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Quantity Zonal Load Cost
Average Standard Deviation
Frequency at Cap
Frequency of Price
Separation
Average Excess (Deficit) Above
LSR
Standard Deviation
Frequency Below
LSR
Frequency Below
TSA
Frequency Below 1-in-5
Average LOLE
Average Customer
Costs
Average of Bottom
20%
Average of Top 20%
($/kW-m) ($/kW-m) (% of draws) (% of draws) (MW) (MW) (% of draws) (% of draws) (% of draws) (events/yr) ($mil/year) ($mil/year) ($mil/year)
Base AssumptionsNEMA/Boston
ISO-NE Proposal (1.0x No TTC) $12.2 $4.1 18.9% 16.9% 743 405 13.7% 13.7% 10.2% 0.109 $946 $497 $1,421NESCOE Modeling Curve $12.2 $4.0 15.1% 17.5% 683 404 15.8% 15.8% 11.0% 0.112 $943 $497 $1,413
ConnecticutISO-NE Proposal (1.0x No TTC) $12.2 $3.9 15.9% 21.9% 615 469 14.1% 10.9% 13.3% 0.120 $1,221 $696 $1,739
NESCOE Modeling Curve $12.2 $3.9 14.0% 21.7% 544 469 17.4% 12.7% 14.7% 0.125 $1,219 $690 $1,725
70% Shocks, Supply Elasticity, and No LumpinessNEMA/Boston
1.0x No TTC $12.2 $3.0 14.2% 21.3% 499 265 12.1% 12.1% 3.4% 0.095 $952 $679 $1,307NESCOE Modeling Curve $12.2 $2.8 9.8% 25.9% 413 265 16.5% 16.5% 4.0% 0.098 $949 $679 $1,282
Connecticut1.0x No TTC $12.2 $2.8 9.5% 28.9% 410 301 12.9% 8.1% 4.6% 0.103 $1,230 $930 $1,674NESCOE Modeling Curve $12.2 $2.7 7.8% 30.8% 320 301 17.7% 11.7% 6.0% 0.108 $1,228 $930 $1,647
Price
Import-Constrained ZonesNESCOE Curve w/ 70% Shocks, Supply Elasticity
▀ Requested analysis of NESCOE proposed curve (1x system ratio, above and below LSR; see figure on slide 23)
▀ With three changes to modeling assumptions that each reduce price volatility and improve reliability: (1) reduce shock sizes to 70% of base; (2) increase supply elasticity (see right); (3) remove supply lumpiness
▀ Combined effect under sensitivity assumptions is a substantial improvement in all price volatility and reliability metrics
Performance
Supply Curves with More Elasticity
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Import-Constrained Zones CT PURA & DEEP: Simulation Requests
▀ CT PURA & DEEP requested simulation results under different combinations of sensitivity assumptions, and using two different LOLE tuning approaches
▀ Sensitivity assumptions would reduce price volatility and increase reliability, including:1. 70% shock sizes 2. No demand shocks3. LOLE capped at the value when local MW are at TSA (i.e. consistent with an assumption of
ISO-NE intervention to restore local MW to TSA)▀ Tuning approaches are conceptually similar to approaches we used system-wide, with
local LOLE tuned to 0.105 LRA target (note: this request contemplates allowing for the violation of the “minimum acceptable” at TSA)
▀ However, because system LOLE is above 0.105 under the revised clearing mechanics, no amount of tuning can restore the zones to this level. We therefore re-interpret this question as tuning the local curves to reach a local adder of 0.005 LOLE (consistent with the LRA delta above NICR)
▀ Re-interpreted tuned curves reflect:1. ISO-NE proposed curve, shifted to a local LOLE adder of 0.005 events/year2. Cap at 1-in-5 LOLE, adjust foot to meet a local LOLE adder of 0.005 events/year
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Import-Constrained Zones CT PURA & DEEP: Tuned CurvesCandidate Curve, Left/Right Shifted to Tune LOLE* Cap at 1-in-5, Foot Adjusted to Tune LOLE*
NEMA
Connecticut
NEMA
Connecticut
Notes:The “truncated LOLE” curves were not possible to develop in NEMA because the LOLE adder at TSA was too low (i.e. the LOLE adder cannot be increased to 0.005 because the LOLE adder at TSA is close to zero).See appendix slide 34 for system simulation results under the same curves.
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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/Boston
ISO-NE Proposal (1.0x No TTC) $12.2 $4.1 18.9% 16.9% 743 405 13.7% 13.7% 10.2% 0.109 $946 $497 $1,421
1.0x (No TTC) Curve, Varying Assumptions70% Shock Size $12.2 $3.5 13.8% 18.9% 544 286 12.5% 12.5% 4.2% 0.098 $949 $585 $1,326LOLE Capped at TSA $12.2 $4.1 18.9% 16.9% 743 405 13.7% 13.7% 10.1% 0.109 $946 $497 $1,421No Demand Shocks $12.2 $3.6 16.9% 25.0% 388 402 16.4% 16.4% 5.7% 0.104 $942 $620 $1,249
1.0x (No TTC) Curve, Shifted to Local LOLE70% Shock Size $12.2 $3.5 13.7% 19.2% (249) 287 67.7% 67.7% 5.7% 0.102 $938 $585 $1,302LOLE Capped at TSA n/a (see note below)No Demand Shocks $12.2 $3.6 16.8% 25.0% (323) 403 78.4% 78.4% 7.0% 0.111 $932 $619 $1,232
Cap at 1-in-5, Foot Adjusted to Local LOLEBase Assumptions $12.2 $3.9 11.6% 19.7% 130 403 43.8% 43.8% 13.6% 0.125 $931 $468 $1,426LOLE Capped at TSA n/a (see note below)LOLE Capped at TSA, No Demand Shocks n/a (see note below)No Demand Shocks $12.2 $3.4 6.1% 28.3% (332) 403 78.8% 78.8% 8.7% 0.121 $929 $544 $1,293
Connecticut
ISO-NE Proposal (1.0x No TTC) $12.2 $3.9 15.9% 21.9% 615 469 14.1% 10.9% 13.3% 0.120 $1,221 $696 $1,739
1.0x (No TTC) Curve, Varying Assumptions70% Shock Size $12.2 $3.3 9.7% 25.3% 461 332 12.5% 8.4% 6.2% 0.105 $1,227 $801 $1,685LOLE Capped at TSA $12.2 $3.9 15.9% 21.9% 615 469 14.1% 10.9% 11.6% 0.114 $1,221 $696 $1,739No Demand Shocks $12.2 $3.5 14.8% 27.3% 406 468 19.1% 14.4% 9.7% 0.116 $1,224 $780 $1,684
1.0x (No TTC) Curve, Shifted to Local LOLE70% Shock Size $12.2 $3.3 9.6% 25.2% 598 332 7.6% 4.8% 5.0% 0.102 $1,229 $802 $1,691LOLE Capped at TSA $12.2 $3.9 15.9% 21.9% 615 469 14.1% 10.9% 11.6% 0.114 $1,221 $696 $1,739No Demand Shocks $12.2 $3.5 14.8% 27.3% 663 468 8.0% 5.1% 7.8% 0.111 $1,227 $780 $1,696
Cap at 1-in-5, Foot Adjusted to Local LOLEBase Assumptions $12.2 $3.7 10.3% 23.0% 855 469 8.0% 5.5% 14.0% 0.125 $1,221 $707 $1,690LOLE Capped at TSA $12.2 $3.8 11.0% 22.2% 637 468 13.9% 10.6% 13.2% 0.123 $1,219 $687 $1,699LOLE Capped at TSA, No Demand Shocks $12.2 $3.2 5.2% 27.2% 593 468 11.1% 6.6% 8.6% 0.120 $1,223 $792 $1,623No Demand Shocks $12.2 $3.1 5.1% 26.3% 667 468 8.5% 5.2% 9.3% 0.121 $1,225 $801 $1,622
Price
Import-Constrained Zones CT PURA & DEEP: Simulation Results
Note: Tuned curves could not be drawn in NEMA in the cases where local LOLE was capped at TSA. Because the local LOLE “adder” becomes close to zero at TSA, the local curve could never be 0.005 events/year above Unconstrained System LOLE.See appendix slide 34 for system simulation results.
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Import-Constrained Zones
UI: What Are Local Prices When LOLE is Similar to System?
Question: “How often would we expect customers in import constrained zones to pay higher capacity prices than customers in the rest of pool for the same level of reliability (as measured by the LOLE metric)?”
▀ We focus on the subset of draws in which: (a) local price separates above system (b) local LOLE is within 0.005 events/year above unconstrained system LOLE
▀ 16% and 2% of draws fall into this subset in NEMA and CT respectively (greater in NEMA because TSA & LSR are right-shifted compared to LRA, and so local LOLE adder is usually very small)
▀ The results in this subset of draws may seem counter-intuitive when taken individually (i.e. why pay a price premium in the zones when local reliability is no worse than rest of pool?)
▀ However, these results are consistent with the overall reliability and price volatility objectives of the demand curve and FCM, because the price premium paid in this subset of draws helps to support sufficient local supply to prevent larger price separation or lower-reliability events from occurring in other years
▀ Further, focusing only on LOLE does not account for the transmission security objective TSA
Draws Average Price Price Standard Deviation
Count % of All DrawsAbsolute
PricePrice Delta
Above SystemAbsolute
PricePrice Delta
Above System
Average Premium as a % of System Price
Average Excess above
LSR
Average Price Premium *
Total Quantity Cleared in (%) ($/kW-m) ($/kW-m) ($/kW-m) ($/kW-m) (%) (MW) ($mil)
NEMA/BostonDraws w/ Price Separation and Similar LOLE 157 16% $16.5 $6.3 $2.6 $3.7 80% (183) $644All Other Draws 843 84% $11.4 $0.1 $3.9 $1.2 2% 915 $14All Draws 1,000 100% $12.2 $1.1 $4.1 $2.9 14% 743 $113
ConnecticutDraws w/ Price Separation and Similar LOLE 16 2% $6.7 $1.1 $4.2 $0.9 22% 422 $150All Other Draws 984 98% $12.3 $1.1 $4.1 $2.7 15% 618 $138All Draws 1,000 100% $12.2 $1.1 $3.9 $2.7 15% 615 $138
v
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Average Price Differential
% of Draws w/ Price Separation and Similar LOLE
When Zones Separate and LOLE
Is Similar
All Other Draws All Draws
(%) ($/kW-m) ($/kW-m) ($/kW-m)
[1] [2] [3] [4]
NEMA/Boston
ISO-NE Proposal (1.0x No TTC) 16% $6.3 $0.1 $1.1
1.5x System Ratio 17% $6.5 $0.0 $1.1
2.0x System Ratio 18% $6.2 $0.0 $1.1
Vertical in Zones and System 9% $10.8 $0.2 $1.1
Vertical in Zones (System Sloped) 15% $6.7 $0.1 $1.1
PJM VRR 17% $6.0 $0.1 $1.1
NESCOE: LSR at 1.2x Net CONE 16% $6.3 $0.1 $1.1
GDF SUEZ: Cap at 2x Net CONE 17% $6.4 $0.0 $1.1
NU: Cap at 1-in-5, Foot at 1-in-87 20% $5.1 $0.1 $1.1
CT PURA/DEEP Tuned 13% $5.6 $0.4 $1.1
Connecticut
ISO-NE Proposal (1.0x No TTC) 2% $1.1 $1.1 $1.1
1.5x System Ratio 13% $4.9 $0.5 $1.1
2.0x System Ratio 17% $4.9 $0.3 $1.1
Vertical in Zones and System 0% $9.6 $1.1 $1.1
Vertical in Zones (System Sloped) 0% $5.9 $1.1 $1.1
PJM VRR 0% $5.2 $1.1 $1.1
NESCOE: LSR at 1.2x Net CONE 2% $4.9 $1.0 $1.1
GDF SUEZ: Cap at 2x Net CONE 5% $5.1 $0.9 $1.1
NU: Cap at 1-in-5, Foot at 1-in-87 22% $4.5 $0.2 $1.1
CT PURA/DEEP Tuned 14% $4.8 $0.5 $1.1
Import-Constrained Zones
UI: Comparison of Statistics Across All Curves▀ Comparing all candidate curves in
instances where:− The zone price-separates, and− LOLE adder in zone is < 0.005
▀ Anywhere from 0-22% of draws depending on the curve
▀ NEMA always shows greater frequency from these draws for any curve drawn to the right of TSA
▀ Average price differential above system is the same across all curves (even though the price differential associated with this subset of draws varies substantially)
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Contents
▀ Introduction▀ Impact of Model Updates▀ Stakeholder Questions
− Import-Constrained Zonal Demand Curves− Export-Constrained Zonal Demand Curves
▀ Summary Comparison of Zonal Demand Curves▀ Appendix
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Export-Constrained ZoneEmera Energy: 1.5x Width Curve
▀ Emera Energy proposed a curve with width 1.5x of system ratio (flatter than proposed)
▀ Results in modest improvement in price volatility in Maine (modest degradation in System LOLE) compared to ISO-NE proposal
Performance
Note: Curve names are labeled based on the stakeholder suggesting those curves for analysis, but do not necessarily reflect that stakeholder’s recommended approach in all cases.
Quantity Zonal Load CostAverage Standard
DeviationFrequency
at CapFrequency
of Price Separation
Average Quantity
Above (Below) MCL
Standard Deviation
Constrained System
LOLE
Unconstrained System
LOLE
Final Customer
Costs
Averageof Bottom
20%
Averageof Top 20%
($/kW-m) ($/kW-m) (% of draws) (% of draws) (MW) (MW) (events/yr) (events/yr) ($mil/year) ($mil/year) ($mil/year)
ISO-NE Proposal (1.0x System Ratio) $10.0 $4.1 4.0% 19.1% (267) 168 0.120 0.109 $287 $120 $4571.5x System Ratio $10.0 $4.0 3.4% 21.8% (218) 168 0.122 0.111 $287 $130 $454
Price
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Quantity Zonal Load CostAverage Standard
DeviationFrequency
at CapFrequency
of Price Separation
Average Quantity
Above (Below) MCL
Standard Deviation
Constrained System
LOLE
Unconstrained System
LOLE
Final Customer
Costs
Averageof Bottom
20%
Averageof Top 20%
($/kW-m) ($/kW-m) (% of draws) (% of draws) (MW) (MW) (events/yr) (events/yr) ($mil/year) ($mil/year) ($mil/year)
ISO-NE Proposal (1.0x System Ratio) $10.0 $4.1 4.0% 19.1% (267) 168 0.120 0.109 $287 $120 $457NESCOE: Foot Same as 1x System Ratio, Cap at MCL $10.0 $4.2 4.5% 16.7% (226) 168 0.122 0.110 $287 $116 $459NESCOE: Kink at Net CONE, Vertical to Cap $10.0 $4.2 4.6% 17.3% (287) 168 0.120 0.109 $287 $121 $460
Price
Export-Constrained ZoneNESCOE: Curves at or Above MCL
▀ NESCOE proposed looking at two curves that would be right-shifted compared to MCL
▀ Both curves perform similarly to the ISO-NE proposal (very small increase in price volatility in both cases; and degradation in system reliability in one case)
▀ Both options would prevent procuring less than MCL supply in Maine in the event of system-wide shortage
Notes: Runs modeled with ISO-NE Proposed curve in NEMA/Boston and Connecticut.Curves names are labeled based on the stakeholder suggesting those curves for analysis, but do not necessarily reflect that stakeholder’s recommended approach in all cases
Performance
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Contents
▀ Introduction▀ Impact of Model Updates▀ Stakeholder Questions
− Import-Constrained Zonal Demand Curves− Export-Constrained Zonal Demand Curves
▀ Summary Comparison of Zonal Demand Curves▀ Appendix
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Curve ComparisonAlternative Importing Zone Curves (Connecticut)
Note: Curves names are labeled based on the stakeholder suggesting those curves for analysis, but do not necessarily reflect that stakeholder’s recommended approach in all cases.
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Quantity Zonal Load Cost
Average Standard Deviation
Frequency at Cap
Frequency of Price
Separation
Average Excess
(Deficit) Above LSR
Standard Deviation
Frequency Below
LSR
Frequency Below
TSA
Frequency Below 1-in-5
Average LOLE
Average Customer
Costs
Average of Bottom
20%
Average of Top 20%
($/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/BostonISO-NE Proposal (1.0x No TTC) $12.2 $4.1 18.9% 16.9% 743 405 13.7% 13.7% 10.2% 0.109 $946 $497 $1,4211.5x System Ratio $12.2 $4.0 13.6% 17.4% 1091 403 6.0% 6.0% 11.5% 0.115 $946 $484 $1,4222.0x System Ratio $12.2 $4.0 12.1% 18.2% 1270 402 3.0% 3.0% 12.1% 0.119 $946 $474 $1,426Vertical in Zones and System $12.2 $6.2 53.6% 10.4% 627 399 16.2% 16.2% 20.1% 0.160 $927 $286 $1,596Vertical in Zones (System Sloped) $12.2 $4.1 21.1% 16.9% 633 405 17.1% 17.1% 10.1% 0.107 $947 $509 $1,418PJM VRR $12.2 $3.9 8.1% 18.6% 566 404 19.7% 19.7% 10.8% 0.111 $942 $499 $1,409NESCOE: LSR at 1.2x Net CONE $12.2 $4.1 18.6% 17.6% 734 405 13.9% 13.9% 10.6% 0.111 $945 $500 $1,418GDF SUEZ: Cap at 2x Net CONE $12.2 $4.0 16.2% 17.1% 967 405 8.4% 8.4% 10.6% 0.111 $948 $499 $1,420NU: Cap at 1-in-5, Foot at 1-in-87 $12.2 $3.8 10.3% 21.4% 726 403 14.4% 14.4% 13.3% 0.125 $938 $466 $1,445CT PURA/DEEP Tuned $12.2 $3.9 11.6% 19.7% 130 403 43.8% 43.8% 13.6% 0.125 $931 $468 $1,426
ConnecticutISO-NE Proposal (1.0x No TTC) $12.2 $3.9 15.9% 21.9% 615 469 14.1% 10.9% 13.3% 0.120 $1,221 $696 $1,7391.5x System Ratio $12.2 $3.8 11.6% 22.8% 930 469 6.1% 4.0% 13.0% 0.120 $1,224 $701 $1,7142.0x System Ratio $12.2 $3.7 10.2% 22.7% 1168 470 2.2% 1.5% 13.0% 0.121 $1,226 $709 $1,698Vertical in Zones and System $12.2 $6.2 52.7% 11.6% 442 447 19.0% 14.2% 24.4% 0.176 $1,200 $388 $1,831Vertical in Zones (System Sloped) $12.2 $4.2 22.4% 18.7% 493 470 18.8% 14.2% 13.4% 0.120 $1,222 $680 $1,778PJM VRR $12.2 $3.8 8.1% 21.4% 421 469 21.8% 17.9% 15.9% 0.131 $1,219 $689 $1,700NESCOE: LSR at 1.2x Net CONE $12.2 $4.0 19.0% 22.7% 595 469 14.7% 11.3% 13.8% 0.122 $1,221 $690 $1,754GDF SUEZ: Cap at 2x Net CONE $12.2 $4.0 16.5% 21.7% 760 469 9.9% 7.0% 12.6% 0.118 $1,223 $689 $1,749NU: Cap at 1-in-5, Foot at 1-in-87 $12.2 $3.7 10.3% 24.6% 1277 471 1.6% 0.8% 13.5% 0.126 $1,226 $708 $1,695CT PURA/DEEP Tuned $12.2 $3.7 10.3% 23.0% 855 469 8.0% 5.5% 14.0% 0.125 $1,221 $707 $1,690
Price
Curve ComparisonPerformance in Import-Constrained Zones
Notes: Curve names are labeled based on the stakeholder suggesting those curves for analysis, but do not necessarily reflect that stakeholder’s recommended approach in all cases. Base case assumes true Net CONE in NEMA/Boston and Connecticut is 10% higher than system.Zonal load costs reflect capacity procurement costs paid by customers in each zone, assuming all zonal CTRs are awarded to local customers.
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Zonal Load Cost
AverageStandard Deviation
Frequency at Cap
Constra ined System
LOLE
Unconstra ined System
LOLE
Average Reserve Margin
Reserve Margin St. Dev.
Frequency Below NICR
Frequency Below
1-in-5 in RoP
AverageAverage of
Bottom 20%
Average ofTop20%
($/kW-m) ($/kW-m) (% of draws) (events/yr) (events/yr) (%) (%) (% of draws) (% of draws) ($mil/yr) ($mil/yr) ($mil/yr)
ISO-NE Proposal (1.0x No TTC) $11.1 $3.8 6.3% 0.120 0.109 12.9% 2.7% 37.2% 10.1% $4,506 $2,685 $6,4281.5x System Ratio $11.1 $4.2 8.7% 0.120 0.115 12.7% 2.7% 41.0% 11.5% $4,509 $2,595 $6,5442.0x System Ratio $11.1 $4.4 9.4% 0.121 0.119 12.5% 2.6% 43.2% 12.1% $4,508 $2,522 $6,575Vertical in Zones and System $11.1 $6.3 44.4% 0.176 0.160 10.7% 1.8% 60.5% 20.1% $4,437 $1,546 $7,017Vertical in Zones (System Sloped) $11.1 $3.6 4.7% 0.120 0.104 13.1% 2.7% 35.6% 8.9% $4,513 $2,669 $6,378PJM VRR $11.1 $3.9 8.1% 0.131 0.111 12.9% 2.7% 38.0% 10.6% $4,500 $2,665 $6,505NESCOE: LSR at 1.2x Net CONE $11.1 $3.8 5.6% 0.123 0.111 12.9% 2.7% 37.9% 10.6% $4,505 $2,657 $6,431GDF SUEZ: Cap at 2x Net CONE $11.1 $3.9 6.5% 0.118 0.111 12.9% 2.7% 37.8% 10.6% $4,510 $2,664 $6,449NU: Cap at 1-in-5, Foot at 1-in-87 $11.1 $4.7 10.2% 0.127 0.125 12.2% 2.5% 47.1% 12.9% $4,500 $2,296 $6,622CT PURA/DEEP Tuned $11.1 $4.4 9.7% 0.130 0.120 12.4% 2.6% 43.4% 12.0% $4,490 $2,421 $6,584
Price Reliability
Curve ComparisonSystem-Wide Performance Impacts
Notes: Curve names are labeled based on the stakeholder suggesting those curves for analysis, but do not necessarily reflect that stakeholder’s recommended approach in all cases. All curves were run with the ISO-NE Proposed 1.0x System Ratio (No TTC) curves for NEMA/Boston and Connecticut and the ISO-NE Proposed 1.0x System Ratio curve in Maine.
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Curve ComparisonAlternative Exporting Zone Curves
Note: Curve names are labeled based on the stakeholder suggesting those curves for analysis, but do not necessarily reflect that stakeholder’s recommended approach in all cases
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Quantity Zonal Load CostAverage Standard
DeviationFrequency
at CapFrequency
of Price Separation
Average Quantity
Above (Below) MCL
Standard Deviation
Constrained System
LOLE
Unconstrained System
LOLE
Final Customer
Costs
Averageof Bottom
20%
Averageof Top 20%
($/kW-m) ($/kW-m) (% of draws) (% of draws) (MW) (MW) (events/yr) (events/yr) ($mil/year) ($mil/year) ($mil/year)
MaineISO-NE Proposal (1.0x System Ratio) $10.0 $4.1 4.0% 19.1% (267) 168 0.120 0.109 $287 $120 $457Vertical $10.0 $4.5 4.9% 13.7% (385) 168 0.118 0.106 $287 $99 $4601.5x System Ratio $10.0 $4.0 3.4% 21.8% (218) 168 0.122 0.111 $287 $130 $4542.0x System Ratio $10.0 $3.8 2.9% 25.2% (177) 168 0.124 0.112 $287 $138 $449
NESCOE: Foot Same as 1x System Ratio, Cap at MCL $10.0 $4.2 4.5% 16.7% (226) 168 0.122 0.110 $287 $116 $459
NESCOE: Kink at Net CONE, Vertical to Cap $10.0 $4.2 4.6% 17.3% (287) 168 0.120 0.109 $287 $121 $460
Price
Curve ComparisonPerformance in Export-Constrained Zones
Notes: Curve names are labeled based on the stakeholder suggesting those curves for analysis, but do not necessarily reflect that stakeholder’s recommended approach in all cases.All curves were run with the ISO-NE Proposed 1.0x System Ratio (No TTC) curves for NEMA/Boston and Connecticut.Base case assumes true Net CONE in NEMA/Boston and Connecticut is 10% higher than system, Maine Net CONE is 10% lower than system .Zonal load costs reflect capacity procurement costs paid by customers in each zone, accounting for CTRs that are awarded to local customers.
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Contents
▀ Introduction▀ Impact of Model Updates▀ Stakeholder Questions
− Import-Constrained Zonal Demand Curves− Export-Constrained Zonal Demand Curves
▀ Summary Comparison of Zonal Demand Curves▀ Appendix
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AppendixUpdated LOLE Calculation and Reporting
System:▀ Previously reported only “System LOLE,” which
reflected the LOLE that ISO-NE would calculate if there were no internal constraints (i.e. “copper sheet” assumption used when estimating NICR)
▀ That metric will now be labeled as “Unconstrained System LOLE” and used as a primary metric for evaluating the system demand curve
▀ Also reporting a new metric “Constrained System LOLE,” which reflects the max of the LOLE of any zone in any one draw (consistent with NPCC definition of system LOLE in the presence of zonal constraints)
Import Zones:▀ Zonal LOLE is affected by MW of supply both within
the zone (determines local events) and outside the zone (determines system events)
▀ Previously calculated zonal LOLE as the maximum of local and system LOLE
▀ Updated approach calculating local LOLE “adder” on top of system events (results very similar to prior approach)
Revised Local LOLE Approach
Local LOLEUnconstrained System LOLE
“Local LOLE Adder”
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AppendixUpdated Local Clearing Approach
System-Wide Clearing Price and Quantity▀ Updated clearing mechanics will produce the same prices as the prior model if there is no price separation (clear on system demand curve)
▀ If importing zones do price-separate, then system-wide prices and quantities will clear below and to the left compared to prior modeled clearing mechanics (which assumed system + all zones supply would clear on the aggregate system demand curve)
▀ Affects approximately 1/3 of draws (any time one or both import zones price separate)
Clearing in Example Draw
Example Draw(See Below)
ExampleDraw
Individual Draws(Each w/ unique
“Residual” System Demand Curve)
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Appendix Range of Import Zone Curves Compared
▀ We tested a range of import zone demand curves under the updated simulation model
− Updated LOLE Calculation− FCM Auction Clearing Rules
▀ Intended to provide stakeholders more information about results that can be expected with varying widths of local curves
▀ General observations:− System reliability and price
volatility worsen with wider zonal curves
− Zonal metrics move in the opposite directions (i.e. local reliability and price volatility improve with wider curves)
ConnecticutCurves Tested Under Updated Model
Note: “1x System (No TTC)” curve applies the system ratio multiplier to NEMA and CT local curves without including the TTC MW in the calculation.
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Reliability System Load Cost
AverageStandard Deviation
Frequency at Cap
Constra ined System
LOLE
Unconstra ined System
LOLE
Average Reserve Margin
Reserve Margin St. Dev.
Frequency Below NICR
Frequency Below
1-in-5 in RoP
AverageAverage of
Bottom 20%
Average ofTop20%
($/kW-m) ($/kW-m) (% of draws) (events/yr) (events/yr) (%) (%) (% of draws) (% of draws) ($mil/yr) ($mil/yr) ($mil/yr)
Vertical $11.1 $3.6 4.7% 0.123 0.107 13.1% 2.7% 35.5% 9.8% $4,508 $2,673 $6,3550.5x System Ratio $11.1 $3.7 5.8% 0.123 0.109 13.0% 2.7% 36.8% 10.1% $4,505 $2,678 $6,413ISO-NE Proposal (1.0x No TTC) $11.1 $3.8 6.3% 0.120 0.109 12.9% 2.7% 37.2% 10.1% $4,506 $2,685 $6,4281.0x System Ratio $11.1 $3.9 7.0% 0.120 0.112 12.8% 2.7% 38.4% 10.8% $4,506 $2,656 $6,4801.25x System Ratio $11.1 $4.1 7.9% 0.119 0.113 12.8% 2.7% 39.7% 11.1% $4,508 $2,632 $6,5121.5x Width $11.1 $4.2 8.7% 0.120 0.115 12.7% 2.7% 41.0% 11.5% $4,509 $2,595 $6,544
Price
AppendixSystem Simulation Results
Note: All runs modeled with a 1x system ratio curve in Maine.
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Quantity Zonal Load Cost
Average Standard Deviation
Frequency at Cap
Frequency of Price
Separation
Average Excess
(Deficit) Above LSR
Standard Deviation
Frequency Below
LSR
Frequency Below
TSA
Frequency Below 1-in-5
Average LOLE
Average Customer
Costs
Average of Bottom
20%
Average of Top 20%
($/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 $12.2 $4.1 21.1% 16.9% 633 405 17.1% 17.1% 10.1% 0.107 $947 $509 $1,4180.5x System Ratio $12.2 $4.1 17.8% 17.3% 768 405 13.1% 13.1% 10.2% 0.109 $946 $503 $1,416ISO-NE Proposal (1.0x No TTC) $12.2 $4.1 18.9% 16.9% 743 405 13.7% 13.7% 10.2% 0.109 $946 $497 $1,4211.0x System Ratio $12.2 $4.0 15.1% 17.6% 916 404 9.4% 9.4% 10.8% 0.112 $946 $496 $1,4161.25x System Ratio $12.2 $4.0 14.4% 17.7% 999 404 7.7% 7.7% 11.1% 0.113 $946 $491 $1,4191.5x Width $12.2 $4.0 13.6% 17.4% 1091 403 6.0% 6.0% 11.5% 0.115 $946 $484 $1,422
ConnecticutVertical $12.2 $4.2 22.6% 18.9% 491 470 18.9% 14.3% 13.7% 0.123 $1,222 $679 $1,7770.5x System Ratio $12.2 $4.0 17.9% 20.8% 521 469 18.1% 13.4% 14.2% 0.123 $1,220 $684 $1,749ISO-NE Proposal (1.0x No TTC) $12.2 $3.9 15.9% 21.9% 615 469 14.1% 10.9% 13.3% 0.120 $1,221 $696 $1,7391.0x System Ratio $12.2 $3.9 13.9% 21.9% 711 469 11.3% 8.2% 13.2% 0.120 $1,221 $690 $1,7321.25x System Ratio $12.2 $3.9 12.9% 23.2% 819 469 8.4% 6.1% 13.0% 0.119 $1,222 $693 $1,7241.5x Width $12.2 $3.8 11.6% 22.8% 930 469 6.1% 4.0% 13.0% 0.120 $1,224 $701 $1,714
Price
AppendixImporting Zones Simulation Results
Note: All runs modeled with ISO-NE Proposed 1x system ratio curve in Maine.
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Zonal Load Cost
AverageStandard Deviation
Frequency at Cap
Constra ined System
LOLE
Unconstra ined System
LOLE
Average Reserve Margin
Reserve Margin St. Dev.
Frequency Below NICR
Frequency Below
1-in-5 in RoP
AverageAverage of
Bottom 20%
Average ofTop20%
($/kW-m) ($/kW-m) (% of draws) (events/yr) (%) (%) (% of draws) (% of draws) ($mil/yr) ($mil/yr) ($mil/yr)
ISO-NE Proposal (1.0x No TTC) $11.1 $3.8 6.3% 0.120 0.109 12.9% 2.7% 37.2% 10.1% $4,506 $2,685 $6,428
1.0x (No TTC) Curve, Varying Assumptions70% Shock Size $11.1 $3.0 1.4% 0.105 0.098 13.1% 2.0% 32.0% 4.2% $4,516 $3,072 $6,028LOLE Capped at TSA $11.1 $3.8 6.3% 0.114 0.109 12.9% 2.7% 37.2% 10.1% $4,506 $2,685 $6,428No Demand Shocks $11.1 $2.8 1.2% 0.116 0.104 13.1% 2.2% 33.6% 5.6% $4,489 $3,024 $5,918
1.0x (No TTC) Curve, Shifted to Local LOLE70% Shock Size $11.1 $3.0 1.3% 0.107 0.097 13.1% 2.0% 31.8% 4.1% $4,505 $3,057 $6,022LOLE Capped at TSA $11.1 $3.8 6.3% 0.114 0.109 12.9% 2.7% 37.2% 10.1% $4,506 $2,685 $6,428No Demand Shocks $11.1 $2.8 1.2% 0.115 0.106 13.0% 2.3% 33.6% 5.6% $4,483 $3,016 $5,913
Cap at 1-in-5, Foot Adjusted to Local LOLEBase Assumptions $11.1 $4.4 9.7% 0.130 0.120 12.4% 2.6% 43.4% 12.0% $4,490 $2,421 $6,584LOLE Capped at TSA $11.1 $4.4 9.3% 0.123 0.118 12.5% 2.6% 42.5% 11.7% $4,487 $2,451 $6,569LOLE Capped at TSA, No Demand Shocks $11.1 $3.9 4.5% 0.120 0.115 12.6% 2.2% 39.9% 7.5% $4,463 $2,682 $6,216No Demand Shocks $11.1 $3.9 4.9% 0.126 0.116 12.6% 2.2% 40.5% 7.5% $4,463 $2,657 $6,234
Price Reliability
AppendixCT PURA & DEEP System Simulation Results
Note: All runs modeled with a 1x system ratio curve in Maine.