heco companies experience with distributed pv...
TRANSCRIPT
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HECO Companies Experience with Distributed PVLisa DangelmaierApril 11 2012
PJM/EPRI/NREL Inverter-based Gen Interconnection Workshop – Distribution Reliability Needs/Studies
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DG Growth from 2009 to 2011
2Summary of Interconnected Distribution Level Penetration on Major Island Grids* DG Penetration = Installed DG MW / Max Feeder Load 2010 data
*
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Tracking Tremendous Growth in Distributed PV
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Red areas indicate circuits with > 15% PV penetration
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Local Circuit Impact – light load, or large projects lead to export
Concerns:1. The above graphs illustrate the need to assess the feeder loading not only at peak periods but also on the days
where the loads are not as high (light load Sundays) – Rule 14H 2. Circuit peaks often not coincident with System peaks 4
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Improved Models to Account for PV as Generation vs Negative Load
Enables more accurate modeling of DG resources for planning
Consistent distribution system model expedites modeling and analysis process
Allows for “what-if” analysis to stay ahead of system change and minimize risks of stranded assets
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Translate feeder level impacts to system level
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Interface Between T&D Models
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SynerGEEUnbalanced Distribution
Aggregated BEW PV Sites
SynerGEE Balanced System
46 kV/12 kV
Aggregated BEW System/PV Sites
PSLF Models
PowerWorldBalanced
138 kV/46 kV Model
PSS/E138 kV Model
PPLUS
Generic PV/Inverter User- Defined
Model
PSS/E400+Sites
PV Data
Individual12 kV Feeder
46 kV System 138 kV System Generation
Reso
urce
s
7000
+Si
tes
900Sites
Data Transfer Point
Distribution Planning
ResourcePlanning
Transmission Planning
Note: Line ratings shown for Oahu system for illustration
Industry Partners: SMUD/HECO High Penetration PV Initiative, BEW Engineering, GL Noble Denton, GIS & EMS providers
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Modeled Variability : 30% PV Penetration Island Wide (light load)
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Color-coded impacts at distribution substations
Simulated results at 30% PV penetration across the islands and impacted areas
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Impact of Variability On LTC Operations
Highlighted % of total days with tap changer count above n > 5 for months of January to June
Increase in count correspond with highest variability months- May and April (light load months)
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Impact of Increasing Distributed PV on Apparent Demand
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MW
Midnight Midnight12 noon
Min-Max output of dispatchable and base generating units
Excess Energy –curtailed
Energy Shortfall must be met by fast starting units
SCADA, feeder caps or new monitoring to account for DG contributions
Typical Hawaii load profile –Evening Peaking
Output of intermittent units
Supply exceeds Demand at Lower Demand Periods –Encroaching into Daytime
Supply does not meet demand at maximum load
DG (PV) changing system daytime load shape
Curtailment ReliabilityMasked Loads
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2008 difference
2011 difference
Comparison of 2008 and 2011 Weekend Actual Loads (HELCO)
• Weekday comparison: evening peak has not significantly changed between 2008 and 2011 but daytime demand has.
• Weekend comparison (light load day): difference between daytime peak and evening peak has increased. 10
Source: HELCO
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Monitoring solar availability and variability at 2 sec SCADA rate. Operators observe correlation of solar irradiance and demand change.
LM-1 solar availability sensors
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Hawaii
Piloting Control Room Situational Awareness Tools to "See" Variability
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59.6
59.7
59.8
59.9
60
60.1
60.2
0
0.5
1
1.5
2
2.5
3
13:20:00 13:21:00 13:22:00 13:23:00 13:24:00 13:25:00 13:26:00 13:27:00 13:28:00 13:29:00 13:30:00
Freq
uenc
y (H
z)
Momentary Fault, Auto-Reclose 6500 Line 2/7/2012 13:20Load Response based on Per Unit Pre-fault Load
FEEDER 11 MW
FEEDER 12 MW
Frequency (Hz)
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PPA, SIA, larger FIT Interconnection Requirements
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•Wind/solar forecasting data•Off-normal frequency ride-through•SCADA telemetry and control (500/250 KVA)•Does not apply to small projects (NEM, smaller FIT)•Working on voltage-ride-through requirements
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Questions/Comments??
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Mahalo
Dora Nakafuji, [email protected] of Renewable Energy PlanningSystem Integration DepartmentHawaiian Electric Co
Lisa [email protected] Superintendent, Production Dept., Hawaii Electric Light Co
HECO MECO HELCO
Family of HEI Utilities
For more information please contact:
mailto:[email protected]�mailto:[email protected]�
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BACKUP MATERIALS
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Recommendations: Identified Gaps & Enhancements to Interconnection Process
Analysis Type Normal Detail Level EnhancementSTEADY STATE STUDIES
Load Flow - Back-feed potential
Peak Load ConditionsComment on equipment setting
(LTC and LDC)
Minimum Daytime LoadInvestigate equipment settings and
impact of changingIrradiance data for capacity vs.
generated power
Tap Changer CyclingStep Maximum output to Minimum
Output at Peak Load, 1% limit in voltage change specified to impact LTC
Time sequential analysis with measured irradiance data over seconds and time delay of LTC
Peak and Minimum daytime load conditions
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Analysis Type Normal Detail Level EnhancementDYNAMIC STUDIES
Dynamic/Stability Studies - All PV trip
Not normally completedMultiple sites/nodal/cluster studies,
PV is dynamic Inverter
Dynamic/Stability Studies - N-1
Not normally completedFull dynamic analysis on range of
site sizes and configurations
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Field Validation
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Ramp tracking through afternoon
Cloud variability during day peak
Morning load risetracked
Source: HELCO17
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Visibility to DG (Data to Output Probability)
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Capturing statistical variation of PV with respect to time and by geographic location.
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Nodal Estimation Approach to Expedite PV Integration Studies
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• Characterize discrete and aggregated circuit load profiles at 12 kV substation (residential, industrial, commercial)
• Expedite circuit evaluations and aggregate DG impacts for planning
• Use reference LM-1 sensors to estimate solar resource output at location
• Extend solar forecasting to account for aggregated impact of behind-the-meter generationHiP-PV Industry Partners: SMUD, BEW
Engineering, GL Noble Denton, NREL, EPRI
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Growth of Variable Distributed Gen
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Excess Energy Curtailment (Feb 2011)
0.000
20.000
40.000
60.000
80.000
100.000
120.000
140.000
160.000
180.000
200.000M
W
TIME
Wind
Geothermal
Hydro
Diesels
CT
Combined CycleSteam
SYSTEM LOAD
Curtailment of wind and geothermal
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59.6
59.7
59.8
59.9
60
60.1
60.2
60.3
0
0.5
1
1.5
2
2.5
3:03:18 3:04:18 3:05:18 3:06:18 3:07:18
Freq
uenc
y (H
z)
MW
/ M
VA
R
Thursday Dec 22 2011
Momentary Fault, Auto-Reclose 6500 Line 12/22/2011 03:03Load Response based on Per Unit Pre-fault Load
FEEDER 11 MW
FEEDER 12 MW
Frequency (Hz)
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Situational Awareness & Decision Support for Operations
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• Improve operational awareness of ramp (0-2hr) conditions and impacts
• Animated images of global horizontal irradiance
• Visual to measured data• NWP forecast for next 6 hours
• Animated visible satellite image
• Actual satellite image for last 6 hours• Simulated forecast of visible image for next 6
hours
Forecasting Industry Partners: EPRI, AWS TruePower, US DOE WFIP, SCE, SMUD, CaISO, UH Manoa, UCSD
SolarSENSE
������HECO Companies Experience with Distributed PV�Lisa Dangelmaier�April 11 2012DG Growth from 2009 to 2011Tracking Tremendous Growth in Distributed PVLocal Circuit Impact – light load, or large projects lead to export Improved Models to Account for PV as Generation vs Negative LoadInterface Between T&D ModelsModeled Variability : 30% PV Penetration Island Wide (light load)Impact of Variability On LTC OperationsImpact of Increasing Distributed PV on Apparent Demand Comparison of 2008 and 2011 Weekend Actual Loads (HELCO)Piloting Control Room Situational Awareness Tools to "See" Variability Slide Number 12PPA, SIA, larger FIT Interconnection RequirementsSlide Number 14Slide Number 15Recommendations: Identified Gaps & Enhancements to Interconnection ProcessField ValidationVisibility to DG �(Data to Output Probability)Nodal Estimation Approach to Expedite PV Integration StudiesGrowth of Variable Distributed GenExcess Energy Curtailment �(Feb 2011)Slide Number 22Situational Awareness & Decision Support for Operations