Demand Response 2010 and Beyond
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Demand Response 2010 and Beyond April 28, 2011 Pete Pengilly
description
Demand Response 2010 and Beyond. April 28, 2011. Pete Pengilly. Demand Response at Idaho Power. Current programs and results Value of Demand Response load reduction Dispatch of Demand Response resources Optimum level of DR reduction for Idaho Power’s system and 2011 IRP Analysis - PowerPoint PPT Presentation
Transcript of Demand Response 2010 and Beyond
Demand Response 2010 and Beyond
April 28, 2011
Pete Pengilly
Demand Response at Idaho Power
• Current programs and results
• Value of Demand Response load reduction
• Dispatch of Demand Response resources
• Optimum level of DR reduction for Idaho Power’s system and
2011 IRP Analysis
• Method and level of payment for Demand Response
• Reporting of Demand Response Peak reduction
• IPUC Case No. IPC-E-10-46: Revise Peak Rewards
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Programs
• Irrigation Peak Rewards– Using cell phone communication and manual intervention to turn
off irrigation pumps during peak times (AMI switch pilot)
• FlexPeak Management– Under contract with EnerNoc to offer demand response to large
commercial and industrial customers
• A/C Cool Credit– Cycles residential A/C units off and on during peak times
Peak History at Idaho Power
• System peak • 3,214 MW June 30, 2008
• System winter peak • 2,528 MW December 10, 2010
• Summer 2009 system peak • 3,031 MW July 22, 2009 (actual-w/o DR)
• Summer 2010 system peak• 2,930 MW June 28, 2010 (actual-w/o DR)
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Summer 2010
Date 6/29/2010 7/16/2010 7/26/2010 8/5/2010
High Temperature (F) 93⁰ 101⁰ 92⁰ 101⁰
A/C Cool Credit (MW) 33 34 35
FlexPeak Management (MW) 30 34 31 33
Irrigation Peak Rewards (MW) 196 222 121
Total (MW) 259 290 31 189
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Idaho Power's Summer And Winter Peaks1976-2010
Summer Peaks Winter Peaks
YEAR
ME
GA
WA
TT
S (M
W)
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2009 IRP : Capacity $/kW Month
8DR ≈ $850/MWh
2009 IRP : Energy $/MWh
2010 Results
09/08/2010 ... 00:00
09/08/2010 ... 00:55
09/08/2010 ...
01:50
09/08/2010 ...
02:45
09/08/2010 ... 03:40
09/08/2010 ... 04:35
09/08/2010 ... 05:30
09/08/2010 ... 06:25
09/08/2010 ... 07:20
09/08/2010 ... 08:15
09/08/2010 ... 09:10
09/08/2010 ...
10:05
09/08/2010 ...
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09/08/2010 ... 11:55
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13:45
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14:40
09/08/2010 ... 15:35
09/08/2010 ... 16:30
09/08/2010 ...
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09/08/2010 ... 19:15
09/08/2010 ...
20:10
09/08/2010 ...
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09/08/2010 ... 22:00
09/08/2010 ... 22:55
1,500
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System Load
7/16/2010
6/29/2010
8/5/2010
MW
Peak Rewards: In 2010 reduced peak load by 222 MW by controlling pumps on 2038 service locations.
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Dispatch Method 2010• Met every Thursday throughout the summer with:
• Program Managers• Power Supply• Generation Dispatch• Transmission Planners• Energy Traders• Day Ahead Operators• Regulatory Affairs
• Considered:• Load Forecast• Temperature Forecast• Generation Availability• On-Peak Energy Prices & Availability• DR Program Parameters/Availability/Dispatch
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1,700
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3,000
A/C Cool -34 MW
Irrig 85 MW
Irrig 94 MW
July -16, 2010
FlexPeak- 34 MW
Irrig 43 MW
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7/16/2010 W/O DR
MW
150 MW
140 MW
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Idaho Power Total Demand Response July 16, 2010
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MW
Hours
6-Jun-2011 16-Jun-2011 26-Jun-2011 6-Jul-2011 16-Jul-2011 26-Jul-2011 5-Aug-2011 15-Aug-2011 25-Aug-20110
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Peak days dispatch line
MW
Fifteen days above dispatch line
3,209 MW
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Theoretical 2011 Dispatch of 310 MW DR
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0 5 10 15 20 250
500
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Peak Day w/Demand Response
Dispatch Line
24 hr day
MW
0:00
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Potential Day 2011 vs. 2010 Actual
7/16/2010W/O DR2011 forcast
MW
Approx. Generation Capacity
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IRP Analysis Results
Minimum
A B C D E F G H I
YearPeak Load
(MW)
60th Hour Peak Load
(MW)
Energy Efficiency
(MW)
Existing and Committed Supply-Side Resources
(MW)
L&R Balance Deficit Position
w/o DR Programs (MW)
Achievable DR with 60 Hour Programs
(MW)
Demand Response
Target (MW)
Operational Target (MW)
2011 3,515 3,209 17 3,120 378 306 306 330
2012 3,430 3,227 34 3,241 155 203 155 310
2013 3,684 3,326 50 3,390 244 358 244 315
2014 3,770 3,422 65 3,386 319 348 319 315
2015 3,854 3,532 79 3,382 393 322 322 321
2016 3,925 3,566 93 3,379 453 359 359 351
2017 3,991 3,588 108 3,374 509 403 403 351
2018 4,056 3,650 122 3,368 566 406 406 351
2019 4,123 3,711 136 3,363 624 412 412 351
2020 4,190 3,827 150 3,358 682 363 363 351
Conclusions:• There is an optimum amount of Demand Response for the
Idaho Power system• In conjunction with the IRP planning process, Idaho Power
plans to set a demand response target that will be updated with each new IRP
• Energy Efficiency department will work to align program design with system needs
• Stakeholders need to be involved in this process• Program design needs to be continually re-assess for
program improvement and increase value• Peak load reporting policies need to be addressed
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IPUC Case No. IPC-E-10-46: Dec 2010
Revision of Irrigation Peak Rewards
• Change the incentive structure: 40% fixed 60% variable
• Include one event in fixed payment
• Change how large customers participate > 1,000 hp
• Modify the opt out option and penalty
• Add the 8-9 p.m. hour on an optional basis and slightly increase
incentive
• Add limitation of participation language based on need
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IPUC Case No. IPC-E-10-46:
Order 32200
• Change the incentive structure: 75% fixed 25% variable
• Do not include one event in fixed payment
• Approved: Change how large customers participate > 1,000 hp
• Approved: Modify the opt out option and penalty
• Approved: Add the 8-9 p.m. hour on an optional basis and slightly
increase incentive
• Do not limit participation based on need
