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RPS Model Methodology. Arne Olson, Partner Doug Allen, Consultant. Contents. Updates to Previous 33% Implementation Analysis Resource Potential, Cost, and Performance Portfolio Selection Methodology. Updates to Previous 33% Implementation Analysis. - PowerPoint PPT Presentation
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RPS Model Methodology
Arne Olson, Partner
Doug Allen, Consultant
2
Contents
Updates to Previous 33% Implementation Analysis
Resource Potential, Cost, and Performance
Portfolio Selection Methodology
Updates to Previous 33% Implementation Analysis
4
Current Analysis Compared to 2009 Implementation Analysis
33% RPS Implementation Analysis was focused on informing state RPS policy
Key tasks:
1. Develop “plausible scenarios” for achieving 33% by 2020
2. Estimate the net ratepayer costs associated with each plausible scenario
3. Highlight key obstacles to reaching the 33% goal, including the need for new transmission and the integration costs of new resources
The current analysis is focused on informing state RPS planning
Key tasks:
1. Develop “plausible scenarios” for achieving 33% by 2020
2. Estimate year-by-year resource build-outs under each alternative scenario
3. Feed information into LTPP proceeding to inform the Commission’s decisions regarding fossil procurement
5
Weaknesses of Previous 33% Implementation Study
New transmission is assumed for most projects
No way to determine which projects could get built without new lines
Renewable projects are selected in aggregated “bundles” and could not be selected individually
Crude methodology for addressing potential out-of-state REC resources (“Out-of-State Early”, “Out-of-State Late”)
Did not look at operational impacts of renewables at such high levels of penetration
Integration costs for intermittent resources based on a rule of thumb
Lack of transparency in handling of short-listed CPUC projects
Project viability ratings not very scientific
6
Key Improvements in Portfolio Development Methodology
Improved handling of transmission requirements for new renewable resources
Allows some resource to be delivered over existing transmission or with minor upgrades
Allows individual selection of Non-CREZ resources
Incorporation of unbundled REC resources
Can now model out-of-state REC-only resources as well as out-of-state CREZs
Incorporation of “Discounted Core” of commercial projects
Projects in advanced stage of permitting and development
7
Other Updates to Analysis
Improved detail on Commercial projects in CPUC ED Database
CREZ assignments
2009 solicitations
Confidential projects either aggregated or excluded to improve transparency
New Aspen environmental scores
Updated resource list based on RETI Phase 2B analysis
Updated RPS Net Short based on:
2009 IEPR Load Forecast
New load decrements for EE and CHP calculated by CPUC
Existing renewable resources from 2008 Net System Power Report
Resource Potential, Cost, and Performance
9
General Approach
Determine renewable resource gap (GWh) in 2020
Compile database of resources available to meet RPS target
Rank available resources based on cost, commercial interest, environmental sensitivity and timeline
Select resources to fill renewable resource gap
10
Determining Demand for Renewables
Demand for renewables in California is based on 2020 RPS target, equal to 33% of eligible retail sales
2020 retail sales based on CEC 2009 IEPR load forecast
Excludes retail sales by small LSEs (<200 GWh/yr)
Estimate quantity of renewable resources online in base year
Used renewable resource “claims” from CEC 2008 Net System Power Report
Added new resources online in 2009 based on ED Database
RPS resource gap is the difference between the 2020 target and the 2009 renewables claims
11
Renewable Net Short
33 33 33
26
54
0
20
40
60
80
100
2009 2020, 20% RPS 2020, 33% RPS
Ren
ewab
le G
ener
atio
n (
TW
h)
Existing Resources RPS Net Short
12
Sources of New Resources to Fill Resource Gap
1. Commercial Projects
ED Database of IOU projects
POU procurement plan data obtained from CARB
2. Additional “Theoretical” Projects
RETI pre-identified and proxy projects for California
WREZ projects for the rest of the WECC
3. Original Renewable DG resource potential estimates
Developed as part of 2010 LTPP
13
Updated ED Database
Analysis incorporates the latest ED Database, including 2009 IOU solicitations
Contracted projects are included individually
Shortlisted projects are aggregated by resource type and zone in cases where there are at least three such projects to preserve confidentiality (otherwise they are left out)
Distribution of projects among zones has changed since previous analysis
CREZ MW GWh
Tehachapi 4,174 11,239
Northwest 1,805 4,137
Pisgah 1,700 3,974
NonCREZ 841 3,831
Imperial South 1,074 3,042
Riverside East 1,042 2,547
Alberta 886 2,422
Carrizo South 849 1,980
Mountain Pass 710 1,720
Nevada C 500 1,415
Colorado 420 1,301
San Diego South 415 1,293
Montana 300 820
Imperial North 109 770
Fairmont 296 752
Arizona 290 737
Solano 240 704
Kramer 250 584
Inyokern 242 566
Distributed Solar - PG&E 244 468
Distributed Solar - SCE 140 290
Round Mountain 86 281
New Mexico 32 238
Santa Barbara 83 238
Palm Springs 77 222
Nevada N 30 212
Imperial East 30 212
Utah-Southern Idaho 90 191
San Bernardino - Lucerne 49 170
Total 17,003 46,357
14
Current Analysis Previous Analysis Current Analysis Previous Analysis
MW GWh MW GWh MW GWh MW GWh
Tehachapi 4,174 11,239 2,038 5,756 Palm Springs 77 222 37 107
Northwest 1,805 4,137 - - Nevada N 30 212 - -
Pisgah 1,700 3,974 800 1,954 Imperial East 30 212 560 1,367
NonCREZ 841 3,831 525 3,118 Utah-Southern Idaho 90 191 - -
Imperial South 1,074 3,042 792 1,944 San Bernardino - Lucerne 49 170 666 1,623
Riverside East 1,042 2,547 2,932 6,855 Baja - - - -
Alberta 886 2,422 - - Barstow - - - -
Carrizo South 849 1,980 - - British Columbia - - - -
Mountain Pass 710 1,720 1,480 3,523 Carrizo North - - - -
Nevada C 500 1,415 30 228 Cuyama - - - -
Colorado 420 1,301 - - Iron Mountain - - 368 897
San Diego South 415 1,293 225 650 Lassen North - - 53 384
Montana 300 820 - - Lassen South - - - -
Imperial North 109 770 569 2,472 Owens Valley - - 55 307
Fairmont 296 752 384 907 San Bernardino - Baker - - - -
Arizona 290 737 - - San Diego North Central - - 87 333
Solano 240 704 150 434 Twentynine Palms - - 67 194
Kramer 250 584 837 2,016 Victorville - - 160 342
Inyokern 242 566 - - Westlands - - - -
Distributed Solar - PG&E 244 468 - - Wyoming - - - -
Distributed Solar - SCE 140 290 - - Needles n/a n/a 747 1,911
Round Mountain 86 281 125 468 Out-of-State Early n/a n/a 2,062 6,617
New Mexico 32 238 - - Out-of-State Late n/a n/a 534 1,304
Santa Barbara 83 238 83 238 Total 17,003 46,357 16,363 45,950
CREZ CREZ
Changes in the ED Database
15
Breakdown of the ED Database
Discounted Core Non-Discounted CoreExcluded from Model
to Preserve Confidentiality
Total ED Database Projects
MW GWh MW GWh MW GWh MW GWh
Biogas 12 84 28 195 - - 40 279
Biomass 158 1,176 8 56 20 149 186 1,381
Geothermal 70 494 439 3,101 336 2,370 845 5,965
Hydro - - 26 79 - - 26 79
Large Scale Solar PV 2,068 5,068 2,087 4,970 975 2,322 5,130 12,359
Small Solar PV 384 758 - - - - 384 758
Solar Thermal 2,744 6,414 1,305 3,050 153 358 4,202 9,822
Wind 3,684 10,049 3,991 10,862 1,098 2,987 8,772 23,898 Total 9,120 24,044 7,883 22,313 2,581 8,186 19,584 54,542
Signed - ApprovedSigned - Pending
ApprovalIn Negotiations
Total Projects Included in RES
CalculatorMW GWh MW GWh MW GWh MW GWh
Biogas 21 144 19 135 - - 40 279
Biomass 89 659 77 573 - - 166 1,232
Geothermal 219 1,547 290 2,048 - - 509 3,595
Hydro - - 26 79 - - 26 79
Large Scale Solar PV 1,138 2,724 1,421 3,591 1,596 3,722 4,155 10,037
Small Solar PV 7 14 268 536 109 209 384 758
Solar Thermal 1,615 3,775 2,434 5,689 - - 4,049 9,464
Wind 2,950 8,034 814 2,249 3,910 10,629 7,675 20,911 Total 6,039 16,896 5,349 14,900 5,615 14,560 17,003 46,357
16
Treatment of Commercial Projects
Commercial projects are divided into two categories:
1. Discounted Core: Project has obtained or has made significant progress towards obtaining a permit
2. Non-Discounted Core: Project has made limited progress towards obtaining a permit
Discounted Core projects are given first priority in the resource selection sorts, reflecting their high probability of development
Non-Discounted Core projects are given priority over generic resources but are not guaranteed development
POU planned resources treated as Non-Discounted core
17
POU Resources
E3 has included POU resource procurement plans in the development of the resource portfolios based on CEC data
POU resources are included as Non-Discounted Core commercial resources
In-State Out-of-State
MW GWh MW GWh
Biogas 145 1,013 - -
Biomass - - 2 12
Geothermal 550 3,884 42 299
Hydro - Small - - 156 478
Solar Thermal 358 836 - -
Solar PV - - - -
Wind 504 1,455 648 1,871
Total 1,557 7,188 848 2,660
18
RETI Phase 2B Database
The updated RETI Phase 2B Database contains site-specific information for renewable resource potential, cost, and performance in California
Out-of-state resources from the WREZ Transmission Model have been incorporated with the RETI data
WREZ estimates of potential represent high-quality remote renewable resources that would require significant transmission upgrades to reach load centers
19
Out of State Renewable Resource Data from E3 Models E3 maintains a database of renewable resource
cost and performance data in the West
Wind and solar data based on NREL GIS modeling
Geothermal and hydro data from EIA
Biomass aggregated from various sources
Additional resource data for BC and Alberta
Used to supplement WREZ data for out-of-state resources (Montana, Colorado, BC, Alberta)
20
Estimates of Statewide DG Potential
As part of the 2010 LTPP, E3 and Black & Veatch collaborated to develop original estimates of the statewide potential of solar PV
The RPS model integrates these estimates, allowing it to evaluate the viability of the development of these resources
RegionEasy to
InterconnectHarder to
InterconnectTotal
North Coast 1148 1440 2588Central Valley 1237 5693 6931South Coast 1890 433 2323Mojave Desert 694 1600 2294TOTAL 4970 9167 14136
21
Resource Cost and Performance
E3 used site-specific data on resource cost and performance where available (RETI and WREZ projects)
Generic assumptions were developed for resources without specific information based on averages of the RETI data (shown below)
Biogas - Landfill
Biogas - Other
Biomass GeothermalHydro - Small
Large Scale Solar
PV
Small Solar PV
Solar Thermal
Wind
Capital Cost ($/kW) 2,750$ 5,500$ 4,522$ 6,379$ 3,300$ 4,500$ 4,500$ 5,300$ 2,371$
Fixed O&M ($/kW-yr) 130$ 165$ 72$ -$ 25$ 50$ 50$ 66$ 60$
Variable O&M ($/MWh) -$ -$ 17$ 38$ -$ -$ -$ -$ -$
Heat Rate (Btu/kWh) 12,070 13,200 14,800 - - - - - -
Capacity Factor (%) 80.0% 80.0% 85.0% 80.6% 35.0% 27.8% 23.7% 26.7% 32.9%
On-Peak Availability (%) 100% 100% 100% 100% 65% 65% 65% 78%* 11%**
LCOE ($/MWh) 92$ 121$ 106$ 148$ 161$ 142$ 216$ 202$ 95$
* On-peak availability for solar thermal varies between 70% and 85% based on CREZ
** On-peak availability shown is for in-state resources; out-of-state wind resources have an on-peak availability value of 20% in California
22
Generic Resource Cost Assumptions
$92 $95 $106$142 $148 $161
$202 $216
0
50
100
150
200
250
Biogas -Landfill
Wind Biomass LargeScale
Solar PV
Geo-thermal
Hydro -Small
SolarThermal
SmallSolar PV
20
20
LC
OE
in
20
08
$/M
Wh
23
Transmission and Geographic Classification of Resources
Each resource is assigned one of three classifications
1. CREZ: resources located within one of the 48 Competitive Renewable Energy Zones (either in California or in other states)
2. Non-CREZ: resources in California or directly across the border that are not located within a CREZ and can be delivered with minor transmission upgrades
3. Out-of-State REC: out-of-state resources that would deliver energy to the local market
24
Transmission Bundles
Resources in CREZs are aggregated into transmission bundles in the following order:
1. Existing transmission bundle
2. Minor upgrade bundle
3. New transmission bundle
Discounted core projects given first priority to fill each transmission bundle
Non-core Commercial projects given next priority to fill the New Transmission bundle
Any remaining transmission capacity in the bundle is allocated to the lowest-scoring generic projects
Up to 3000 MW of new transmission allowed for each CREZ
25
Examples of Transmission Capacity Allocation
300
600
1500
400 361
1000
0
200
400
600
800
1000
1200
1400
1600
(1)
Ex
isti
ng
Tra
ns
mis
sio
n
(2)
Inc
rem
en
tal
Up
gra
de
(3)
Ne
wT
ran
sm
iss
ion
(1)
Ex
isti
ng
Tra
ns
mis
sio
n
(2)
Inc
rem
en
tal
Up
gra
de
(3)
Ne
wT
ran
sm
iss
ion
Example Buildup 1 Example Buildup 2
Av
aila
ble
Ca
pa
cit
y (
MW
)
Discounted Core Commercial Projects Theoretical Projects
26
Examples of Transmission Capacity Allocation
0
500
1000
1500
2000
2500
3000
Example 1 Example 2 Example 3
Av
aila
ble
Ca
pa
cit
y (
MW
)
Existing Transmission Minor Upgrades New Line
Discounted Core Commercial Projects Theoretical Projects
27
Out-of-State REC Resources
Out-of-State RECs previously included in two “zones” (“Out-of-State Early” and “Out-of-State Late”)
New model can select REC resources individually
Assume physical limitations on wind integration for each region
REC resources priced at long-run “Green Premium” or Cost minus Value
REC resources optimized for access to transmission, not for resource quality – RECs are allowed for average quality resources, not best sites
Pricing based on long-run cost, not REC market price forecast (analogous to in-state resources)
No pricing distinction between different types of RECs (bundled vs. unbundled, with or without delivery requirement)
28
Unbundled Out-of-State REC-Only Transaction
Leg 1: Developer to Mid-C
Mid-C Market
Leg 2: CAISO to load
Pure REC transaction with no energy purchase requirement and no delivery requirement
Developer sells energy at Mid-C
California LSE purchases REC from developer at LCOE minus Mid-C price
Separately, California LSE arranges for energy transaction from CAISO market to load
California LSE never owns energy
No incremental imports to California
29
Out-of-State REC with Delivery Requirement
Leg 1: CA utility to
Mid-C
Mid-C Market
Leg 2: CAISO to load
REC transaction with energy purchase requirement and delivery requirement
California LSE purchases energy and REC from developer at LCOE of wind facility and sells energy at Mid-C
Separately, California LSE arranges for energy transaction from CAISO market to load
California LSE rebundles REC with transaction from Mid-C to CAISO that would have occurred anyway!
No incremental imports to California
Leg 3: Mid-C to CAISO
30
Pricing of Out-of-State REC vs. In-State Resource
In-State Resource priced at LCOE, ratepayer impact is cost relative to market value or “Green Premium”
Out-of-State REC priced directly at “Green Premium”
Energy and capacity values vary by market (higher in California)
Pricing is the same for all flavors of RECs
In-State Wind Resource
Out-of-State Wind REC
Levelized Cost of Wind Energy $ 90.00 $ 75.00
Integration Costs in Local Market $ 6.00 $ 6.00
Energy Value in Local Market (Mid-C or Palo Verde) $ (55.00) $ (45.00)
Capacity Value in Local Market (Mid-C or Palo Verde) $ (5.00) $ -
Net Cost to CA Ratepayers ("Green Premium") $ 36.00 $ 36.00
REC Price $ - $ 36.00
Example of In-State vs. REC-only Pricing
31
Physical Limits on Out-of-State REC SupplyM
arke
t V
alu
e o
f W
ind
En
erg
y $/
MW
h
MW of Intermittent Renewables
Initially, wind displaces gas resources
More wind reduces market prices and raises integration costs
Value decreases significantly as wind displaces baseload
There is a practical limit to how much intermittent energy each zone can easily accept
32
Physical Limits on Out-of-State REC Supply
There is a practical limit to how much intermittent energy each zone can easily accept
Mar
ket
Val
ue
of
Win
d E
ner
gy
$/M
Wh
MW of Intermittent Renewables
Initially, wind displaces gas resources
More wind reduces market prices and raises integration costs
Value decreases significantly as wind displaces baseload
E3 limited the REC supply based on a simplified representation
33
Limits on Wind Penetration
Ability to easily absorb wind is limited to load served with flexible generation
E3 estimated hourly flexible generation in each zone:
Load – Nuclear – Coal – Base Hydro + Export Transmission Capacity
Wind limit is min value
Other regions also have RPS requirements – assume CA can soak up 50% of each region’s limit
6,461 MW2,257 MW
738 MW404 MW
1,231 MW461 MW
229 MW47 MW
0 MW0 MW
3,665 MW1,371 MW
3,968 MW1,939 MW
2,135 MW 947 MW
1,700 MW850 MW
2,211 MW808 MW
13,745 MW
Total limit on wind in regionWind available to California
Portfolio Selection Methodology
35
Resource Selection Methodology
1. Calculate project score for each resource
2. Allocate lowest-scoring out-of-state theoretical projects to other states until all non-CA WECC RPS targets for 2020 are satisfied
3. Rank remaining CREZ projects and select to fill transmission bundles
4. Calculate aggregate score for each transmission bundle
5. Rank transmission bundles against individual non-CREZ and REC resources
6. Select resources and bundles to meet 33% RPS target in 2020
36
Detailed Portolio Development
Resource Sort for Local Use
Potential CREZ ResourcesPotential Non-CREZ and
REC Resources
Resource Sort for CA Use as RECs
Resource Sort for CA Use Towards RPS
Resources Remaining After Local Sort
Resource Sort for Existing Tx
Resources on Existing Transmission
Resources Remaining After Existing Tx Sort
Resource Sort for New Tx
New Transmission Bundles
Resources Remaining After Local Sort
Non-CREZ and REC Resource Rankings
Resources Selected for Local Use
Resources Selected for CA RPS Portfolio
37
Project Scoring Methodology
Each project is scored on a 0-100 scale based on four metrics (0 is better):
Net Cost
Environmental Score
Commercial Interest Score
Timing Score
Final score for each project is a weighted average of the four individual metrics
Weights are user-defined and vary by scenario
38
Net Cost Score
Cost score is based on a modified version of the RETI Ranking Cost
Includes integration and T&D avoided costs
Scores are converted to 0 – 100 scale, bounded by the model’s lowest and highest net cost resources
Modified RETI Ranking Cost
+ Levelized cost of energy
+ Interconnection (gen-tie) costs
+ Deemed integration costs
+ Levelized, per-MWh incremental transmission costs
– T&D avoided costs
– Energy value
– Capacity value
= Final project ranking cost
39
Environmental Score
Handicaps resources in areas where environmental issues might hinder development
Considers a variety of factors:
Disturbed lands
Right-of-Way
Significant species
Air quality
Others
Scores for each resource in each CREZ on 0-100 scale
CREZ NameTotal for Biomass
Total for Geotherm
alTotal for Solar PV
Total for Solar
ThermalTotal for
WindPV Rural
DGPV Urban Ground
PV Urban Roof
Barstow 40.3 34.2 34.2 35.3 28.9 24.5 9.9 0.0Carrizo North 32.1 27.1 25.5 26.5 24.4 21.1 8.8 0.0Carrizo South 31.5 26.9 25.1 25.8 25.6 22.0 10.0 0.0Cuyama 35.5 28.8 29.0 30.8 27.2 24.5 10.0 0.0Fairmont 30.9 30.1 35.7 36.4 29.0 24.8 9.4 0.0Imperial East 41.1 31.2 26.2 27.2 25.4 22.5 9.9 0.0Imperial North-A 35.9 26.1 21.4 21.8 24.5 18.1 7.8 0.0Imperial North-B 49.9 34.8 28.6 29.5 34.7 22.4 8.5 0.0Imperial South 46.2 31.7 24.1 24.7 27.5 19.9 8.5 0.0Inyokern 30.9 29.4 33.4 33.9 26.3 24.6 9.9 0.0Iron Mountain 38.5 28.6 22.4 22.5 22.0 21.1 10.0 0.0Kramer 22.8 22.2 27.2 27.6 19.7 17.5 6.2 0.0Lassen North 30.5 31.1 33.0 34.2 31.7 25.6 10.0 0.0Lassen South 24.7 32.5 45.7 52.9 49.7 20.3 5.0 0.0Mountain Pass 40.3 33.5 35.8 36.3 29.4 25.8 9.7 0.0Owens Valley 38.3 30.5 25.4 26.7 24.4 20.9 10.0 0.0Palm Springs 50.5 33.0 29.2 31.8 29.1 21.3 6.8 0.0Pisgah 37.5 27.2 21.1 21.3 20.8 20.5 10.0 0.0Riverside East 28.9 23.8 20.6 20.7 20.5 20.1 9.8 0.0Round Mountain-A 23.1 22.5 23.7 24.3 23.1 21.8 10.0 0.0Round Mountain-B 40.3 36.3 39.5 43.7 35.4 27.1 10.0 0.0San Bernardino - Baker 38.3 29.3 23.5 24.2 22.8 20.9 10.0 0.0San Bernardino - Lucerne 42.4 38.0 43.0 44.1 31.9 27.9 9.8 0.0San Diego North Central 57.3 51.9 69.1 75.3 73.6 41.1 9.5 0.0San Diego South 34.1 31.2 34.3 37.0 29.5 24.6 9.9 0.0Santa Barbara 27.1 23.8 26.9 31.1 22.7 15.4 4.9 0.0Solano 34.6 25.0 25.0 26.6 36.3 16.6 5.0 0.0Tehachapi 29.8 25.6 23.2 23.8 23.5 20.6 9.7 0.0Twentynine Palms 38.9 29.6 24.4 25.1 23.2 21.5 10.0 0.0Victorville 39.2 34.2 38.4 38.9 28.0 25.8 9.4 0.0Westlands 26.4 16.7 10.5 10.9 10.1 9.5 4.5 0.0Arizona 36.2 27.8 23.1 23.5 22.7Nevada 36.8 37.4 43.1 46.2 41.9Oregon 45.9 39.6 36.9 37.6 36.3Baja 45.7 41.6 51.7 56.2 51.5Other 45.9 39.6 36.9 37.6 36.3
Median for CA NonCREZ 35.9 29.6 26.9 27.6 26.3 21.5 9.8 0.0
40
Commercial and Timing Scores
Commercial Score: Scale of 0-100 reflecting contracting activity of California utilities
Commercial projects receive a score of 0, while generic projects receive a score of 100
POU-planned projects considered “Commercial” and receive score of 0
Timing Score: Gives better score to resources that can be developed on a relatively short time scale
Online date < 2010 gets 0, > 2021 gets 100
For ED database projects, online dates filed with the applications
For other resources, dates based on size and type of project
41
Selection of RPS Portfolio
Each transmission bundle is assigned an aggregate score based on an average of the constituent resources and compared against individual non-CREZ and RECs resources
Discounted Core Projects are selected first unless in New Transmission bundle
After Discounted Core, resources & bundles with the lowest score are selected to fill the 2020 RPS gap