Government’s Evolving Role in Resource Planning and Environmental Protection Arthur H. Rosenfeld, Commissioner California Energy Commission April 19, 2002 (916) 654-4930 [email protected].US
Government’s Evolving Role in Resource Planning and Environmental Protection
Arthur H. Rosenfeld, CommissionerCalifornia Energy Commission
April 19, 2002
(916) [email protected]
2
Percent of Air Emissions in the U.S. from Fossil Fuel Use
98%91%
97%
52%
85%
0%
20%
40%
60%
80%
100%
120%
CO2 SO2 NO2 VOC COSource: U.S. EPA 1998 Emissions Trends Report and U.S. DOE-EIA Emissions of Greenhouse Gases in the U.S.
3
Emission Rate for NOx from Selected Plants Less than 100 MW -- August 2001 Source: Federal EPA Acid Rain Program, Continuous Emissions Monitoring System
0.00
0.25
0.50
0.75
1.00
1.25
1.50
1.75
2.00
2.25
lbs
of N
Ox
per M
Wh
Subset of units in California, ranked in order of NOx emission rate
4
ISO Load Duration Curves for The Past Two Years
15,000
20,000
25,000
30,000
35,000
40,000
45,000
Hours in the year
MW
2000
2001
5
The Cost of Meeting the Peak
15,000
20,000
25,000
30,000
35,000
40,000
45,000
All Hours in the year
MW
0
100
200
300
400
500
600
700
800
900
1000
$/M
Wh
Total Cost of Production per MWh (including debt service and operating cost)
ISO Load Duration Curve (MW)
Simple Cycle Combined Cycle
6
The Cost of Meeting the "Super Peak"
15,000
20,000
25,000
30,000
35,000
40,000
45,000
Top 10% of Hours in the year
MW
0
200
400
600
800
1000
1200
1400
1600
1800
2000
$/M
Wh
Total Cost of Production per MWh (including debt service and operating cost) from Simple Cycle Turbine
ISO Load Duration Curve (MW)
7
Cal ISO Daily Peak LoadsJanuary 1, 2000 - December 31, 2000
20
25
30
35
40
45
50
Jan-00
Feb-00
Mar-00
Apr-00
May-00
Jun-00
Jul-0
0
Aug-00
Sep-00
Oct-00
Nov-00
Dec-00
GW
Peak Day August 16 - 43.5 GW
Commercial AC
Residential AC
8
Electricity Use in California
• 2/3 of all electricity (kWh) is used in buildings• 50% of buildings in PG&E are in “Block 50” (exempted
from rolling blackouts)• 40% of Peak Demand is due to Air Conditioning plus
Lighting
9
Top Ten Peak Energy Uses/Sectors
(assumes a 50,000 MW peak)
0
1,000
2,000
3,000
4,000
5,000
6,000
7,000
8,000
Com A
C
Res AC
Assembly
Indu
stry
Com Ligh
t
Com M
isc
Res Misc
TCU Buil
dings
Ag & W
ater P
umpin
g
Process
Indu
stry
Res Refr
igerat
or
End-Use/Sector
Meg
awat
ts
15% 14%
11% 11%
7% 6%
4% 4% 4% 4%
10
CEC has Two Types of Regulatory AuthorityRelated to Demand Response
• Building and Efficiency Standards– Title 20 and 24 Update with adoption in 2003 and implementation in 2005– Everything from efficient air conditioners to white roofs
• Load Management Powers– New buildings -- first priority– Then most existing buildings
• CEC feels responsible for the 23,000 interval meters installed with state funds– 16,000 meters are in; 7,000 more by summer– Covers 25% of the peak load of the state– However, only Time-of-Use tariffs in widespread use
• Concerns regarding non-specific nature of TOU – Same price in all summer afternoons regardless of system load,
system condition, or wholesale price
11
• Load Management Tools Are Increasingly Cost-Effective– Interval Meters and Communication– Price Responsive Thermostats– Lighting Controls– Other Process Modifications
• Hourly Electric Rates Are Still in Pilot Stage– For load with new meters (> 200 kW), CPUC requires TOU rates
and offers emergency load management incentives– But has yet to combine these into an hourly tariff– In other jurisdictions, hourly rates have
• reduced the cost to serve load and• enabled firms to reduce their costs of operation
Demand Response to Time-Dependent Prices
12
Critical Peak Pricing (CPP) -- My Visionbased on Gulf Power tariff
CPP varies empirically to reduce demand at critical locations and times
0
5
10
15
20
25
30
35
Pric
e (c
ents
/kW
h)
Standard TOUCritical Peak PriceStandard Rate
Sunday Monday Tuesday Wednesday Thursday Friday Saturday
Curtailment Signal
Variable CPP
13
Gulf Power GoodCents Select Tariff
• Reduces need during critical or near critical periods (emergencies -- present or expected --, very high prices)– Summer Peak Load Reductions of 2.1 kW per house (1st hour)– Winter Peak Load Reduction of 2.7 kW per house (1st hour)
• 4-hour reduction roughly 1 kW• 96% Customer Satisfaction Rating
– Cost savings, greater control and better information• Improves competitive position of Gulf Power in wholesale
markets
14
Critical Peak Pricing (CPP)e.g. Gulf Power residential GoodCents Select tariff
0
5
10
15
20
25
30
35
Pric
e (c
ents
/kW
h)
Standard TOUCritical Peak PriceStandard Rate
Sunday Monday Tuesday Wednesday Thursday Friday Saturday
Curtailment Signal
15
Proposed System for Demand Response in New Homes & Small Commercial Buildings
Load Data1
Price/Proxy/
Curtailment Signal1
Interval Meter Δ$=$1001
Communicating Thermostat
Δ$=$502
Cost of Avoided Load: $100-200 per kW
1. Utility responsible for signal, communications, meter, and load data.2. Builder responsible for communicating thermostat.
16
Georgia Power’s Voluntary 2-part RTP Program
• Customer bill = Part 1 + Part 2– Part 1 based on historical load profile– Part 2 based on price responsive departures from load profile
• Historical load profile is from previous year– Called Customer Baseline Load (CBL)
• a list of hourly loads for entire year• Part 1 is the CBL x TOU tariff
– What you expect to pay if you don’t respond to real-time price• Part 2 is the hourly departures from CBL
– Enables customer to buy additional kWh when prices are low– And sell back kWh when prices are high
• Saves 17% at ~$1/kWh on hot afternoons
17
A High-Tech Firm and Real Time Prices
8,000
9,000
10,000
11,000
12,000
13,000
14,000
15,000
16,000
17,000
18,000
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24hour of the day
KW
load
0
10
20
30
40
50
60
70
80
90
100
Rea
l Tim
e Pr
ice
(cen
ts p
er K
Wh)
Actual KW
Baseline KW
TOUTOU
RTP
18
Summary of Time-of-Use (TOU), Critical Peak Pricing(CPP), and Real-Time (RTP) Prices
• Time-of-Use (TOU) is typically 3 time blocks published in advance for entire season– Peak, Shoulder, Off-Peak– Can’t foresee weather or equipment failures
• Critical Peak Pricing (CPP) is a high price imposed for a few days a year when system conditions are critical or near critical– A discount is given during off peak hours– Customer pays the critical peak price when invoked by the utility
• a day ahead forecast of CPP offers additional time for response
• Real-Time Pricing (RTP) is hourly real-time marginal cost of a kWh– Reflects hot weather, scarcity, or equipment failure
• a day ahead forecast of RTP offers additional time for response
19
Load Management with Time-Dependent (Dynamic) Pricing
• MICRO-Economic Benefits– Leads to lower costs– Lowers risk of market power– Treats supply and demand symmetrically– Independent of regulated, deregulated, or hybrid industry structure
• Issues– Understanding how loads will respond– Additional study regarding voluntary vs. mandatory
• Impact on customers– Stable industry structure; credit-worthy participants– Clear, consistent government regulation
20
My Vision of Tariff Options
• Residential and Small Commercial– Default = CPP– Hedge = TOU
• Industrial and Large Commercial– Default = CPP– Hedge = TOU– Option = RTP (voluntary)
21
4o F Thermostat Rise for a 10-ton Rooftop A/C
4-hour average saves one-third of A/C, ~1W/sq. ft.
22
59th Street Building - Hourly Averaged LoadsAll A/C Loads - 11 Tons
Curtailment = Setpoint + 4 Deg. (1 to 5 PM)
0.0
0.5
1.0
1.5
2.0
2.5
3.0
3.5
4.0
9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24
Hour
Load
(kW
/100
0 Sq
uare
Fee
t)
Curtailment Day kW Baseline Day kW
IMPACTS / 1000 sf:Avg. kW (1-5PM) = 1.0
Average Hourly Data -- All AC units
From: Ed Hamzawi, SMUD, Oct. 20, 2000
SMUD
23
59th. St. Building - 5 Minute Interval LoadsSecond Floor Lights
Curtailment = 30% Reduction In Lighting Level (1 to 5 PM)
0.0
0.5
1.0
1.5
2.0
2.5
3.0
11:0
0
11:1
5
11:3
0
11:4
5
12:0
0
12:1
5
12:3
0
12:4
5
1:00
1:15
1:30
1:45
2:00
2:15
2:30
2:45
3:00
3:15
3:30
3:45
4:00
4:15
4:30
4:45
5:00
5:15
5:30
5:45
6:00
Time
Loa
d (k
W)
Curtailment Day kW Baseline Day kW
5- Minute Data (Lights)
From: Ed Hamzawi, SMUD, Oct. 20, 2000
SMUD
24
E-20 T Average Load per CustomerMay to August 2000 and 2001
0
1,000
2,000
3,000
4,000
5,000
6,000
5/15 5/22 5/29 6/5 6/12 6/19 6/26 7/3 7/10 7/17 7/24 7/31 8/7 8/14 8/21
kWh
2000
2001