Reducing Water Resources Vulnerability of Climate Change through Adaptive Management
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Transcript of Reducing Water Resources Vulnerability of Climate Change through Adaptive Management
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8/9/2019 Reducing Water Resources Vulnerability of Climate Change through Adaptive Management
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Aris GeorgakakosHuaming YaoMartin Kistenmacher
Integrated Decision Support: Reducing Water Resources Vulnerability toClimate Change through Adaptive Management
Integrated Decision Support FrameworkGCM Scenarios, Downscaling, Hydrology, Water Resources
Climate Change Assessments for Northern CaliforniaCurrent vs. Adaptive Policies; Historical vs. Future Scenarios; Vulnerability
Conclusions/Further AssessmentsMitigation potential of adaptive, risk based management
Kosta GeorgakakosNick GrahamFang-Yi Cheng
Cris Spencer
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Generate consistent climate forcing sequences ofRainfall and temperature.
River/ReservoirPlanning & Management
Simulate soil moisture,evapotranspiration, runoff,and streamflow.
GCM ScenariosDownscaling
Simulate current andadaptive mgt. policiesand assess impactson water uses.
Watershed Hydrology
VulnerabilityAssessmentandMitigation Potential
Integrated Modeling Framework
SanJ
oaqu
inRive
r
San Luis
Clair Engle Lake
Trinity Power Plant
Lewiston
Lewiston
JF Carr
Whiskeytown
Shasta
Keswick
ShastaSpringCr
Keswick
Oroville
Thermalito
Folsom
Natoma
New Melones
Tulloch
Goodwin
Oroville
Folsom
Nimbus
Melones
Tracy
Pumping
Banks
Pumping
SanJ
oaqu
inRive
r
AmericanRiv
er
Feath
erRiv
er
Sacram
entoRiver
TrinityRiver
ClearCreek
YubaR
iver
BearRi
ver
Delta-Mendota Canal
California Aqueduct
ONeillForebay
To Dos Amigos PP
To Mendota Pool
Sacramento San JoaquinRiver DeltaReservoir/
Lake
Power Plant
Pumping Plant
River Node
Reservoir/
Lake
Power Plant
Pumping Plant
Reservoir/
Lake
Power Plant
Pumping Plant
River Node
ISV
IFT
IES,IMC,IYB,ITI
DDLT,DBS,DCCWD,DNBA
DDM
DFDM
DDA
DSF
DSB
Black Butte
NewBullards Bar
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CLIMATEMODEL:NCARCCSM3.0 (COUPLEDMODEL)
SCENARIO: A1B MIDDLELEVELSCENARIO
DECLININGEMISSIONSAFTER2050
MAXCO2CONCENTRATONOF~715PPMAT2100
RESOLUTION: ~120KMHORIZONTALRESOLUTION
26VERTICALLAYERS
6HRSTEMPORALRESOLUTION
VARIABLESUSED:
3D
ATMOSPHERIC
VARIABLES
TWOINPUTSETS:1970 2019 AND2050 2099
GoodLargeScalePrecipitationCorrespondence
ofHistorical19501999runwithNCEP
Reanalysis1948
1997
for
West
Coast
Climate Scenarios
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OROGRAPHICPRECIPITATION
GRIDDED
MODEL
WINDFLOWFROMQUASISTEADYSTATEPOTENTIALTHEORYFLOW
WATERSUBSTANCESOURCE/ADVECTIONMODELWITHKESSLERMICROPHYSICS
10X10SQKMSPATIALAND6HOURLYTEMPORALRESOLUTION
SURFACETEMPERATUREGRIDDEDMODEL
INTERPOLATION/ADJUSTMENTOF
CCSM3.0
LOW
LEVEL
TEMPERATURE
OVER
TERRAIN
SURFACEENERGYBALANCEMODEL(OROGRAPHICANDSNOW/SOILMODELCOUPLING)
10X10SQKMSPATIALAND6HOURLYTEMPORALRESOLUTION
GISBASEDSYSTEMFORCATCHMENTDELINEATIONANDPRODUCTIONOFMAPAND MAT
Reference:HRCGWRI:http://www.energy.ca.gov/pier/project_reports/CEC5002006109.html
Dynamic Downscaling: Mean Areal Precipitation and Temperature
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ADAPTATIONOF
NWS
OPERATIONAL
SNOW
ACCUMULATION
AND
ABLATION
MODEL
ADAPTATIONOFNWSOPERATIONALSOILWATERACCOUNTINGMODEL
KINEMATICROUTINGTHROUGHRIVERNETWORKFORALLBASINS
HydrologicModelDomain
OrovilleSubcatchments
Oroville HistoricalESPReliabilityDiagrams
Watershed Hydrology: Snow, Soil, and Channel Modeling System
Reference:HRCGWRI:http://www.energy.ca.gov/pier/project_reports/CEC5002006109.html
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PrecipitationDifference(mm/6hrs) FebTemperatureDifference(oC) Feb1800Z
Futurewintersarewarmerandwetter(athigherelevations)thanthehistorical.
SimulatedFlows:
Future
Historical
Futureflowsaresomewhathigher
andoccur
earlier
(Shasta/Oroville)
Selected Results: Temperature, Precipitation, Streamflow
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SanJ
oaqu
inRive
r
San Luis
Clair Engle Lake
Trinity Power Plant
Lewiston
Lewiston
JF Carr
Whiskeytown
Shasta
Keswick
ShastaSpringCr
Keswick
Oroville
Thermalito
Folsom
Natoma
New Melones
Tulloch
Goodwin
Oroville
Folsom
Nimbus
Melones
Tracy
Pumping
Banks
Pumping
SanJ
oaqu
inRive
r
AmericanRiv
er
Feath
erRiv
er
Sacram
entoR
iver
Trinity
River
ClearC
reek
Yuba
River
BearRi
ver
Delta-Mendota Canal
California Aqueduct
ONeill
Forebay
To Dos Amigos PP
To Mendota Pool
Sacramento San Joaquin
River DeltaReservoir/Lake
Power Plant
Pumping Plant
River Node
Reservoir/
Lake
Power Plant
Pumping Plant
Reservoir/
Lake
Power Plant
Pumping Plant
River Node
ISV
IFT
IES,IMC,IYB,ITI
DDLT,DBS,DCCWD,DNBA
DDM
DFDM
DDA
DSF
DSB
Black Butte
New Bullards Bar
Northern California River and ReservoirSystem Schematic
Trinity River System (Clair Engle Lake,Trinity Power Plant, Lewiston Lake, LewistonPlant, JF Carr Plant, Whiskeytown, ClearCreek, and Spring Creek Plant);
Shasta Lake System (Shasta Lake, ShastaPower Plant, Keswick Lake, Keswick Plant, andthe river reach from Keswick to Wilkins);
Feather River System (Oroville Lake, OrovillePower Plants, Thermalito Diversion Pond,Yuba River, and Bear River);
American River System (Folsom Lake,Folsom Plant, Natoma Lake, Nimbus Plant,Natoma Plant, and Natoma Diversions);
San Joaquin River System (New MelonesLake, New Melones Power Plant, Tulloch Lake,Demands from Goodwin, and Inflows fromthe main San Joaquin River); and
Bay Delta (Delta Inflows, Delta Exports,Coordinated Operation Agreement--COA, andDelta Environmental Requirements).
River and Reservoir Modeling System
Objectives:Water SupplyEnergy GenerationEnvironment
EcologyRecreation
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202615.5546300San Luis80
20106757Tulloch70
25712731100800New Melones60
102283470327Folsom50
3537.8852.2900640Oroville40
434711671068900Shasta302840.2312231000Whiskeytown20
261731323802145Clair Engle Lake10
SmaxSm inHmaxHm inReservoir NameReservoir
ID
202615.5546300San Luis80
20106757Tulloch70
25712731100800New Melones60
102283470327Folsom50
3537.8852.2900640Oroville40
434711671068900Shasta302840.2312231000Whiskeytown20
261731323802145Clair Engle Lake10
SmaxSm inHmaxHm inReservoir NameReservoir
ID
1502New Melones13.52Nimbus
2103Folsom
6006Oroville
753Keswick
6595Shasta
1502Spring Creek141.42JF Carr
0.351Lewiston
1402Trinity
Capacity (MW )UnitsPower Plant
1502New Melones13.52Nimbus
2103Folsom
6006Oroville
753Keswick
6595Shasta
1502Spring Creek141.42JF Carr
0.351Lewiston
1402Trinity
Capacity (MW )UnitsPower Plant
River Nodes
Lewiston
JF Carr
Clear Creek
Spring Creek
Keswick
WilkinsFeather
American River
Freeport
Goodwin
SJR above Stanislaus
SJR at Vernalis
Antioch
Delta Exit
Tributary Inflows
Trinity
Whiskeytown
Shasta
Keswick-Wilkins
Oroville
Yuba River
Bear River
Folsom
Sacramento Miscellaneous
Eastside streams
Delta Miscellaneous streams
New Melones
San Joaquin River
Water SupplyThermalito
Folsom Pumping
Folsom South Canal
OID/SSJID
CVP Contractors
CCWD
Barker Slough
Federal Tracy PP
Federal Banks On-Peak
Federal Banks Off-Peak
Federal Banks PP Total
Federal Banks PP CVC
Federal Banks PP - Joint Point
Federal Banks PP Transfers
North Bay Aqueduct
State Banks PP
State Tracy PP
Delta Mendota Canal
Federal Dos Amigos
Federal O'Neil to Dos Amigos
San Felipe
Cross Valley Canal
Federal Exchange O'Neil
Federal Exchange San Luis
South Bay/San Jose
State Dos Amigos
Delta Consumptive Use
Freeport Treatment Plant
Yolo Bypass
Transfer Inflow
AFRP (Anadromous Fish Restoration Plan)
Clear Creek Below Whiskeytown Lake (Trinity)
Below Keswick Dam (Sacramento)
Below Nimbus Dam (American)
River and Reservoir Modeling System (2)
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Current Policy
Generate inflow forecastsmedian trace (HA).
Determine water year type (DWR: C/D/N/AN/W).
Adjust base demands based on year type. Determine next month reservoir releases to
- meet water delivery targets and minimumrequired flows at various river nodes,
assuming no extra releases are required to meetDelta demands (X2) and pumping to South CA.
If X2 requirements and south CA delivery targetsare not met, increase releases according to COA(roughly 25/75 rule).
If deficits persist, allocate water to meet X2 first,then south CA water deliveries.
Repeat at the next month.
River and Reservoir Modeling System (4)Current and Adaptive Management Policies
Adaptive, Risk-based Policy
Generate inflow forecastsfull ensemble (HA).
Determine reservoir releases for the next 9
months to- meet water delivery targets and minimumrequired flows at various river nodes,
- meet environmental and ecological Deltarequirements associated with the X2,location and Delta outflow,
- generate as much energy as possible, and
- maintain high reservoir levels andsufficient carry-over storage.
(System-wide, stochastic optimization;Not according to the COA. )
Apply first month release and repeat.
Main Policy Differences
Current Policy Adaptive Policy Focuses on current month. Optimizes over the next 9 months. Deterministic. Risk based.
Adjusts demand targets twice a year. Re-optimizes every month. Follows COA in extra water allocation. Finds optimal allocation strategy each time.
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Water DistributionFlow RegulationHydro Plant Operation
Emergency Response
Monthly Decisions Releases/Energy
Target Conditions
State VariablesPlanning Tradeoffs
Water Supply/Allocation Energy Generation Carry-over Storage Env.-Ecosystem Management
Development Tradeoffs
Urban/Industrial Agriculture Power System Socio-economic & Ecological
Sustainability
Operational Tradeoffs
Flood Management Water Distribution Energy Generation Env.-Ecosystem Management
Benefit/Impact Functions Water Supply Energy Flood Damage Env.-Ecosystem
Scenario/Policy Assessment
Monthly / Several Decades
Actual HydrologicConditions
Actual Demands
Climate-HydrologicForecasts
Demand Forecasts Water Food Energy Env.-Ecosystem
Climate-HydrologicForecasts
Demand Forecasts Water Supply Power Load/Tariffs Flood Damage Env.-Ecosystem Targets
Inflow Scenarios
Development/DemandScenarios Water/Energy Water/Benefit Sharing Environmental Sustainability
Daily Decisions Releases/Energy
Target Conditions State Variables
Benefit/Impact Functions Water Supply Energy Flood Damage
Env.-Ecosystem
Near Real Time Decision Support
Hourly / 1 Day
Mid/Short Range Decision Support
Daily, 6-Hourly, or Hourly / 1 Month
Long Range Decision Support
Weekly, 10-Day or Monthly / 1-2 Years
Infrastructure Develpmnt.Water Sharing CompactsSustainability Targets
Management Policy
INFORM DSS: OverviewMultiple Objectives, Time Scales, & Decision Makers
ManagementAgencies
/Decisions
PlanningAgencies/Decisions
OperationalPlanningandManage
ment
Off-lin
e
Assessments
Adaptive Management System (INFORM DSS)
Reference:HRCGWRI:http://www.energy.ca.gov/pier/project_reports/CEC5002006109.html
System-wide, stochastic optimization
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Assessment Criteria
Lake Levels, SpillageWater Supply Reliability
Energy Generation
Bay Environment (X2)
others.
Simulation Horizon1970 to 2019 (Historical)
2050 to 2099 (Future)
9-month Forecast-Decision Horizon
(Monthly time steps)
Management Policy
Inflow Forecasting
River/ReservoirSimulation
Reservoir Mgt.Basin wide
One Step System
Simulation
Inflow Scenario
Demand Scenario
Regulation Policy
Assessment Process
SanJ
oaqu
inRive
r
San Luis
Clair Engle Lake
Trinity Power Plant
Lewiston
Lewiston
JF Carr
Whiskeytown
Shasta
Keswick
ShastaSpringCr
Keswick
Oroville
Thermalito
Folsom
Natoma
New Melones
Tulloch
Goodwin
Oroville
Folsom
Nimbus
Melones
Tracy
Pumping
Banks
Pumping
SanJ
oaqu
inRive
r
AmericanRiv
er
Fea
therRiv
er
SacramentoR
iver
TrinityRiver
ClearCreek
Yuba
River
BearRi
ver
Delta-Mendota Canal
California Aqueduct
ONeillForebay
To Dos Amigos PP
To Mendota Pool
Sacramento San Joaquin
River DeltaReservoir/Lake
Power Plant
Pumping Plant
River Node
Reservoir/
Lake
Power Plant
Pumping Plant
Reservoir/
Lake
Power Plant
Pumping Plant
River Node
ISV
IFT
IES,IMC,IYB,ITI
DDLT,DBS,DCCWD,DNBA
DDM
DFDM
DDA
DSF
DSB
Black Butte
NewBullards Bar
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Inflow Comparison (Historical vs. Future Scenario)
Average future inflows are somewhat higher.(Trinity 6.3%; Oroville 10%; Shasta 4.3%; Folsom 5.6%.)
Minimum future inflows are considerably lower indicating more severe droughts(27% reduction).
Future inflows are more variable.
Wet season shifts earlier.
Trinity Monthly Mean
0
500
1000
1500
2000
2500
3000
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Trinity His
Trinity Fut
Total Reservoir Inflows
0
2000
4000
6000
8000
10000
12000
14000
16000
18000
20000
0 10 20 30 40 50 60 70 80 90 100
Exceedance of Probability (%)
TAF/Year
Future
Historical
Trinity Historical vs. Future Inflows
System Historical vs. Future Inflows
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Lake Levels: Current vs. Adaptive Policies forHistorical and Future Scenarios
Lake levels exhibit considerably greater seasonal and annual variability in the futurescenario.
System conservation storage is used up in the future scenario. Drought vulnerabilityincreases.
Adaptive DSS policy exhibits higher lake levels and less spillage than current policy.
System Storage Sequences; Historical Period
0
2000
4000
6000
8000
10000
12000
Jan-7
4
Jan-7
6
Jan-7
8
Jan-8
0
Jan-8
2
Jan-8
4
Jan-8
6
Jan-8
8
Jan-9
0
Jan-9
2
Jan-9
4
Jan-9
6
Jan-9
8
Jan-0
0
Jan-0
2
Jan-0
4
Jan-0
6
Jan-0
8
Jan-1
0
Jan-1
2
Jan-1
4
Jan-1
6
Jan-1
8
TAF
His/DSS
His/CurrentPolicy
System Storage Sequences; Future Period
0
2000
4000
6000
8000
10000
12000
Jan-74
Jan-76
Jan-78
Jan-80
Jan-82
Jan-84
Jan-86
Jan-88
Jan-90
Jan-92
Jan-94
Jan-96
Jan-98
Jan-00
Jan-02
Jan-04
Jan-06
Jan-08
Jan-10
Jan-12
Jan-14
Jan-16
Jan-18
TAF
Future/DSS
Future/CurrentPolicy
Historical Future
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Water Deliveries: Current vs. Adaptive Policies forHistorical and Future Scenarios
Current policy provides higher amounts during wet years and lower during dry years.Adaptive DSS policy is more balanced and reliablereduces vulnerability.
Current policy WS during most severe drought (TAF): 4,798 (Historical); 2,545 (Future)Adaptive DSS WS during most severe drought (TAF): 4,923 (Historical); 4,949 (Future)
System Water Delive ries, Historical Inflows
0
1000
2000
3000
4000
5000
6000
7000
8000
9000
0 10 20 30 40 50 60 70 80 90 100
Exceedance of Probability(%)
TAF/Year
His/DSS
His/CurrentPolicy
System Water Deliveries, Future Inflows
0
1000
2000
3000
4000
5000
6000
7000
8000
9000
0 10 20 30 40 50 60 70 80 90 100
Exceedance of Probability(%)
TAF/Year
Future/DSS
Future/CurrentPolicy
Historical Future
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Energy Generation: Current vs. Adaptive Policies forHistorical and Future Scenarios
Annual System Energy, Historical Period
0
1000
2000
3000
4000
5000
6000
7000
0 10 20 30 40 50 60 70 80 90 100
Exceedance of Probability (%)
GWH/Year
His/DSS
His/CurrentPolicy
Annual System Energy, Future Period
0
1000
2000
3000
4000
5000
6000
7000
0 10 20 30 40 50 60 70 80 90 100
Exceedance of Probability (%)
GWH/Year
Future/DSS
Future/CurrentPolicy
Historical Future
Average energy generation increases by 5% in the future scenario under both policies.
Firm energy generation decreases by 10% under the Adaptive Policy and 29% underthe Current Policy.
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Delta Outflow and X2 Location: Current vs. Adaptive Policies forHistorical and Future Scenarios
Adaptive DSS policy meets Delta outflow and X2 requirement in both scenarios.
Current Policy violates Delta outflow and X2 requirement (by 28 kilometers) in futuredroughts.
Current Policy Adaptive DSS Policy
Delta Outflow
X2 Location
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Performance Differences (%) ofFuture relative to Historical Scenario
Future vs. Historical Period
27.9
3.0
-47.0
3.5
-21.4
35.0
14.5
7.7
0.5
3.9
-9.2
0.0
-60
-50
-40
-30
-20
-10
0
10
20
30
40
Precent(%)
Current Policy
DSS
Avg. Spillage Avg. WS
Min. WS
Avg. Energy
Firm Energy
X2 Violation
Future vs. Historical Period
27.9
3.0
-47.0
3.5
-21.4
35.0
14.5
7.7
0.5
3.9
-9.2
0.0
-60
-50
-40
-30
-20
-10
0
10
20
30
40
Precent(%)
Current Policy
DSS
Avg. Spillage Avg. WS
Min. WS
Avg. Energy
Firm Energy
X2 Violation
Current policy worsens in the future scenario: More spillage (27.9%), less minimum water deliveries (47%),
less firm energy (21.4%), and significant X2 and delta outflow violations (35%).+ Increased average water deliveries (3%) and energy generation (3.5%).
Adaptive DSS policy more robust between historical and future scenarios:+ Increased average water deliveries (7.7%), increased minimum water deliveries
(0.5%), increased average energy (3.9%), and no X2 and delta outflow violations. Increased spillage (14.5%), less firm energy (9.2%).
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DSS vs. Current Policy
-2.1 -3.5
2.6-0.1
2.80.0
-12.3
0.9
94.4
0.2
18.8
-35.0
-50
-30
-10
10
30
50
70
90
110
Precent(%)
Historical
Future
Avg. Spillage Avg. WS Min. WS Avg. Energy Firm Energy
X2 Violation
DSS vs. Current Policy
-2.1 -3.5
2.6-0.1
2.80.0
-12.3
0.9
94.4
0.2
18.8
-35.0
-50
-30
-10
10
30
50
70
90
110
Precent(%)
Historical
Future
Avg. Spillage Avg. WS Min. WS Avg. Energy Firm Energy
X2 Violation
Adaptive DSS vs. Current Policy differences are minor in the historical scenario.
Adaptive DSS policy is notably more robust in the future scenario with respect toall criteria, especially minimum water supply, firm energy, Delta requirements, andspillage.
There are nonlinear interactions and tradeoffs underlying system response and
performance against the different criteria. Such assessments serve to quantify andcommunicate these interdependencies.
Performance Differences (%) ofDSS relative to Current Policy
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Future A1B scenario portents intensifying water stresses (due to seasonal inflowshifts and higher inflow variability) and higher vulnerability to extreme droughts.
Adaptive, risk based, reservoir regulation strategies are self tuning to the changingclimate, deliver more robust performance than current management practices, and
can considerably mitigate the negative impacts of increased water stresses.
Effective implementation of adaptive, risk based, reservoir regulation strategies require
more flexible laws and policy statutes (COA, heuristic rules, etc.), a new level of institutional cooperation for water resources management, and
capacity building of agency personnel in modern decision support methods.
Conclusions
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Climate
Forecasts
DecisionRules
Impact Forecasts
Flood Damage, Water Supply,Energy Generation, AgriculturePublic Health, etc.
HydrologicForecasts
Impacts
p
Uncertainty Management: Climate Hydrology Management
u: Static/Fixed
u: Dynamic/Adaptive
Adaptive decision rules can manage forecastuncertainty.
Heuristic regulation rules cannot.
H H H (P, P ) ,Q (T,, Q T{ } f [ S , , k ]),
=
{ , (P, P ) (T, T ) }
S S SS(Q,Q ),(
{ }
f [ ...)S , , ,
I, I
u(S ) k, ]
=
=
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Further Work
Bracket cloud influence in climate downscaling component.
Incorporate impacts ofsea-level rise.
Assessments ofother GCM scenarios (A2, B1, etc.) to investigate the sensitivity of thefindings presented herein.
Assessments with daily and sub-daily temporal resolution to quantify climate changeimpacts on other system functions and outputs (flooding, energy generation markets,ecosystem response, etc.).
Multi-stressor assessments including demand and land use change.
Conjunctive, statewide surface water groundwater assessments.
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The INFORM project was sponsored by the NOAA Climate Program Office, the CaliforniaEnergy Commission PIER Program, and the CALFED Program.
Contributors included several scientists and managers from the California Department ofWater Resources, the Bureau of Reclamation, the US Army Corps of Engineers,NOAA/NWS/CNRFC, NOAA CPO, and others.
The Climate Change INFORM application was funded by the Energy Commission PierClimate Change Program. We thank Guido Franco for his support and guidance, and RobHartman of CNRFC for making available operational historical data.
Acknowledgements