resolve modeling overview - california public utilities ... · 12/16/2016 · resolve modeling...
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RESOLVE ModelingOverview
CPUC IRP WorkshopDecember 16, 2016
Nick Schlag, Sr. Managing ConsultantArne Olson, Partner
Jimmy Nelson, Consultant
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Agenda
RESOLVE model background & overview
Key constraints impacting portfolio development
Summary of model inputs
Examples of model outputs
RESOLVE BACKGROUND
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Defining the New PlanningProblem
Capacity planning paradigm hasshifted with the increasingquantities of variable renewableresources
• RPS targets
• GHG reduction goals
The new planning problemconsists of two relatedquestions:
1. How many MW of dispatchableresources are needed to(a) meet load, and (b) meet flexibilityrequirements on various time scales?
2. What is the optimal mix of newresources, given the characteristics ofthe existing fleet of conventional andrenewable resources?
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The Renewable IntegrationChallenge
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Many studies have highlighted centralrole of renewables in decarbonizingelectricity sector
Primary drivers of renewableintegration challenges at highpenetrations:
• Renewable oversupply during low load periods
• Inflexible conventional generation
• Must-run resources
• Technical constraints on ramping, minimumstable levels, minimum up and down times
• High costs associated with cycling
• Small balancing areas or constrainedinteractions with neighboring regions
Research has shifted to focus on gridintegration solutions
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Optimal Solution Balances Non-Renewable Solutions with Overbuild
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In reality, theintegrated
resource planningquestion hasmany more
dimensions thanshown here
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RESOLVE Co-optimizes Investmentand Operational Decisions
RESOLVE is a linear programallows portfolio optimizationacross a long time horizon (10-20years)
Fixed costs capture capital,financing, and fixed O&Massociated with new physicalinfrastructure
Operational detail focuses onprimary drivers of renewableintegration challenges
RESOLVE may select portfoliofrom a variety of potential“solutions,” including:
• Renewable overbuild
• Energy storage
• Advanced demand response
• Conventional gas generation
• Gas retrofits
RESOLVE ObjectiveFunction
RESOLVE ObjectiveFunction
Fixed Costs of New Resources• Renewables• Energy storage• Demand response• Thermal
Fixed Costs of New Transmission
Total System Operating Costs• Variable O&M• Start costs• Fuel costs• Carbon
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RESOLVE minimizes the NPV of total costs across a 20+year time horizon
• Additional weight applied to last year of analysis to account for end effects
• Because of computational complexity, RESOLVE is typically not used to modelall years in analysis horizon
Example Model Time Horizon
20202018 2022 2024 2026 2028 2030 2032 2034 2036 2038
In each modeled year, the portfolio is explicitlymodeled, and total cost is calculated as the sum offixed costs of investment and operating costs
In intermediate years, the total cost of the portfoliois calculated by linear interpolation between the twoadjacent modeled years
Decisions made withinone year carry forward to
subsequent years
Example of ‘modeledyears’ shown above is
shown to illustrateRESOLVE functionality but
does not necessarilyrepresent the final setthat will be used in IRP
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RESOLVE & the IRP ScenarioDevelopment Process
Each candidate plan, future, and sensitivityrepresents a lever (or combination of levers) thatcan be adjusted in RESOLVE to capture theintention of the scenario
In each sensitivitycase, a single fixed
input to RESOLVEis varied to
evaluate its impacton the objectivefunction and the
least-cost portfolio
For each alternative candidate plan, RESOLVEassumes specific resources are added to theportfolio for evaluation against the ‘Base’ Plan
KEY CONSTRAINTS INPORTFOLIODEVELOPMENT
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Key Constraints in RESOLVE
Renewables portfolio standard
GHG planning target
System planning reserve margin
Local capacity deficiencies
Resource technical potentials
System operating requirements
Generator operating characteristics
Required portfolioattributes &characteristics
Limits on availableresources
Constraints onsystem operations
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Renewables Portfolio Standard
RESOLVE selects new resources to meet arenewable net short in each year
RPS constraint is based on delivered renewableenergy, so renewable portfolio is “overbuilt” tooffset for potential generation lost to curtailment
Renewable net shortselected by RESOLVE
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Greenhouse Gas Planning Target
RESOLVE allows specification of a GHG planning target,which constrains the portfolio on an annual basis
No GHG credit is given for exports from CAISO(consistent with ARB inventory accounting)
GHG constraint, when binding, may result in renewableportfolios that exceed the statutory RPS target
≤GHG PlanningTarget[tons CO2]
GHG PlanningTarget[tons CO2]
PhysicalEmissions Rate
[tons/MMBtu]
PhysicalEmissions Rate
[tons/MMBtu]
CAISO Fuel Burn[MMBtu]
CAISO Fuel Burn[MMBtu]
GasCCGTGas
CCGT
Gas CTGas CT
Gas ICEGas ICE
GasCHPGasCHP
DeemedEmissions Rate
[tons/MWh]
DeemedEmissions Rate
[tons/MWh]
UnspecifiedImports
[MWh]
UnspecifiedImports
[MWh]
GHG planning targetreflects the collectiverequired emissions
targets for the LSEs ofCAISO
GHG planning targetreflects the collectiverequired emissions
targets for the LSEs ofCAISO
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System Planning Reserve MarginConstraint
In each year modeled, RESOLVE imposes a planning reservemargin constraint on the total CAISO generation fleet
Contribution of each resource to PRM requirement depends onits attributes
≤PRM Requirement1-in-2 peak x 115%
PRM Requirement1-in-2 peak x 115%
Based on NQC list
Calculated in RESOLVEvia ELCC surface
Planning assumption
Based on forecast 1-in-2 peak load impact
Function of capacity &duration
Available CapacityAvailable Capacity
Thermal NQCThermal NQC
Hydro NQCHydro NQC
Renewable ELCCRenewable ELCC
ImportsImports
Demand ResponseDemand Response
StorageStorage
PRM constraint designedto ensure that sufficientgeneration capability isavailable to meet load
during system peakconditions; constraint is
unlikely to be bindingexcept in cases thatassume substantial
retirements of existingfleet
PRM constraint designedto ensure that sufficientgeneration capability isavailable to meet load
during system peakconditions; constraint is
unlikely to be bindingexcept in cases thatassume substantial
retirements of existingfleet
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Local Capacity DeficiencyConstraint
The constraint on local capacity requires the totalamount of new capacity associated with local areasto exceed the sum of all local deficiencies
The addition of local RA constraints providesadditional location-specific value for candidateresources that can be used to meet local needs
≤Local Deficiency[MW]
Local Deficiency[MW]
Assumed NQC[%]
Assumed NQC[%]
New Resources[MW]
New Resources[MW]
Gas CCGT/CTGas CCGT/CT
StorageStorage
Distributed PVDistributed PV
Demand ResponseDemand Response
Local RA constraintdesigned to ensure that
sufficient generationcapability is available tomeet load in local areas
during peak periods
Local RA constraintdesigned to ensure that
sufficient generationcapability is available tomeet load in local areas
during peak periods
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Renewable Resource TechnicalPotential
Northern CaliforniaLassen North, Round Mountain,Sacramento River
SolanoCentral Valley North & Los Banos
WestlandsGreater CarrizoCarrizo North, Carrizo South,Cuyama, Santa Barbara
Greater ImperialImperial East, Imperial North, Imperial South,San Diego South, San Diego North Central
Mountain Pass & El Dorado
Riverside East & Palm Springs
Southern California DesertIron Mountain, Pisgah, TwentyninePalms, San Bernandino - BakerTehachapi
Kramer & InyokernBarstrow, Kramer, San Bernandino – Lucerne,Victorville, Inyokern
Example renewable resource andtransmission development zones inRESOLVE model built for CAISO• Renewable-driven transmission build
solved for within each zone• Transmission costs factor into optimal
resource selection
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System Operating Requirements
System operating costsincluded in objective functionusing a linear (LP) productioncost model
• Zonal representation of WECCregion with transmissionconstraints
Additional operationalrequirements are imposed toreflect CAISO operations:
• Spinning reserves
• Load following reserves
• Regulation reserves
• Frequency response
Captures operational impacts ofrenewable integration challenges
Renewables
Gross Load
Net Load
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Plant Operational Constraints
Hourly operations is constrained by many factors:
Hydro constraints:• Daily energy budget• Daily Pmax• Daily Pmin• Hourly ramping
Hydro constraints:• Daily energy budget• Daily Pmax• Daily Pmin• Hourly ramping
Gas generator constraints:• Pmax• Pmin• Min up/down time• Max hourly ramp
Gas generator constraints:• Pmax• Pmin• Min up/down time• Max hourly ramp
Transmission constraints:• Minimum/maximum flowTransmission constraints:• Minimum/maximum flow
Renewable constraints:• Hourly availabilityRenewable constraints:• Hourly availability
Storage constraints:• Pmax• Pmin• Energy neutrality
Storage constraints:• Pmax• Pmin• Energy neutrality
SUMMARY OF KEY INPUTS
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Key Model Inputs
RESOLVE requiresdetailed inputs on boththe demand side (loadforecasts, loadmodifiers, candidateresources) and supplyside (existingresources, candidateresources)
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(5) Time-of-use rates (+/-) (6) Final retail load
(4) Electric Vehicles (+)
(2) Energy Efficiency (-)
(3) Behind-the-Meter PV (-)
(1) Consumption
Load Forecast by Component
Load forecastincorporates multipledemand-sideadjustments:
• Energy efficiency
• Behind-the-meter PV
• Electric vehicles
• Time-of-use rates
Each adjustment ismodeled with anindependent profile,allowing RESOLVE tocapture changes inthe load shapethrough time
Primary data source:CEC IEPR DemandForecast
Shape from (1)
Resultingshape
Shape from (2)
Resultingshape
Shape from (3)
Resulting shape
Shape from (4)
Resultingshape
Shape from (1)
Final shape
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Load shapes for CAISO and other WECC BAs based on2007-2009 historical period
Renewable shapes derived from NREL’s latest wind andsolar data sets:
NREL Wind Prospector (link)
• 126,000 sites• 5-min temporal resolution• 2007-2013 historical period
Load and Renewable Profiles
NREL Solar Prospector (link)
• 120,000 sites• 1-min temporal resolution• 2007-2013 historical period
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Existing & Planned CAISO Renewable Portfolio
Primary sources:
• CAISO conventional generators: CPUC NQC list
• Non-CAISO generators: TEPPC 2026 Common Case
• CAISO existing renewables: CPUC IOU Contract Database
Existing & Planned CAISO Conventional Fleet
Existing Generation Resources
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Resource Cost & Potential
For each candidate resource, RESOLVE requires inputassumptions to specify:
• Technical potential (MW): total available resource that mat be selected
• Fixed costs ($/kW-yr): annualized cost of investment + ongoingmaintenance
• Operating characteristics: e.g. hourly profiles for variable resources;operational constraints & variable costs for thermal & storage resources
Primary sources:• Renewables: RPS Calculator Cost & Potential Assessment (Black & Veatch)
• Gas generation: California Cost of Generation (CEC)
• Advanced DR: 2015 California Demand Response Potential Study (LBNL)
• Storage: market research (E3)
SUMMARY OF RESOLVEOUTPUTS
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Summary of RESOLVE Outputs
RESOLVE produces a variety of outputs that mayinform planning decisions
• Incremental resource portfolio (MW)
• Fixed costs of new investments ($)
• System-wide operational cost ($)
• Renewable curtailment (GWh)
• CAISO GHG emissions (MMTCO2e)
• CAISO fuel consumption (MMBtu)
• System-wide GHG emissions (MMTCO2e)
• System-wide fuel consumption (MMBtu)
• Shadow prices of key constraints ($ per unit)
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- Scenario 1a Scenario 2 Scenario 3CAISO simultaneous export limit 2,000 8,000 8,000Procurement Current practice Current practice WECC-wideOperations CAISO WECC-wide WECC-widePortfolio Composition (MW)California Solar 7,601 7,804 3,440California Wind 3,000 1,900 1,900California Geothermal 500 500 500Northwest Wind, Existing Transmission 1,447 562 318Northwest Wind RECs 1,000 1,000 0Utah Wind, Existing Transmission 604 604 420Wyoming Wind, Existing Transmission 500 500 500Wyoming Wind, New Transmission 0 0 1,995Southwest Solar, Existing Transmission 0 500 500Southwest Solar RECs 1,000 1,000 1,000New Mexico Wind, Existing Transmission 1,000 1,000 1,000New Mexico Wind, New Transmission 0 0 1,962Total CA Resources 11,101 10,204 5,840Total Out-of-State Resources 5,551 5,166 7,694Total Renewable Resources 16,652 15,370 13,534
Energy Storage (MW) 972 500 500
Example Outputs: Resource BuildCAISO SB350 Regionalization Study
Scenarios shown hereanalogous to “candidate
plans” in IRP
Scenarios shown hereanalogous to “candidate
plans” in IRP
Optimalresource mix
adjusts toreflect changesin economicsof operations
(S1a – S2) andincreased
availability ofhigh qualityrenewables(S2 – S3)
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Example Outputs: Shadow PricesCAISO SB350 Regionalization Study
RESOLVE can produceshadow prices on keymodel constraints toinform planningdecisions
Marginal cost of RPScompliance varies byscenario
• Reflects the marginal costof procuring an additionalMWh of renewablegeneration
• Also represents themarginal cost ofrenewable curtailment toratepayers
-
5
10
15
20
25
30
35
40
45
2016 2020 2025 2030
$/M
Wh
Year
Marginal RPS Compliance Cost
Scenario 1a
Scenario 2
Scenario 3
$40
$20
$5
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Example Outputs: SensitivitiesCAISO SB350 Regionalization Study
Fixed Costs ($MM) Scenario 1a Scenario 2 Scenario 3Base assumptions $3,292 $2,612 $2,492A. High coordination under bilateral markets $3,003 $2,612 $2,492B. High energy efficiency $2,790 $2,214 $2,098C. High flexible loads $3,138 $2,643 $2,522D. Low portfolio diversity $3,196 $2,301 $2,192E. High rooftop PV $3,256 $2,418 $2,312F. High out-of-state resource availability $3,104 $2,526 $2,443G. Low cost solar $3,137 $2,627 $2,490H. 55% RPS $4,385 $3,221 $3,044
Annual savings from regional integration range from$391 million to $1 billion per year under 50% RPS
• High flexible loads and high energy efficiency reduce savings
• Low Portfolio diversity, high rooftop PV, and higher RPS increase savings
• High out-of-state availability has limited effect on savings
Sensitivities shownhere analogous to“sensitivities” (or
futures) in IRP
Sensitivities shownhere analogous to“sensitivities” (or
futures) in IRP
Scenarios shownhere analogous to
“candidateplans” in IRP
Scenarios shownhere analogous to
“candidateplans” in IRP
Thank You!
Energy and Environmental Economics, Inc. (E3)101 Montgomery Street, Suite 1600San Francisco, CA 94104Tel 415-391-5100http://www.ethree.com