california load management standards and how they are expected to spur innovation
DESCRIPTION
California Load Management Standards and How They are Expected to Spur Innovation. Commissioner Arthur H. Rosenfeld, Ph.D California Energy Commission Berkeley Wireless Research Center Granlibakken , CA --- June 1, 2009. Demand Response Event on 7/9/2008 28 Sites Shed 2.2MW. - PowerPoint PPT PresentationTRANSCRIPT
California Load Management Standards and How They are Expected to Spur Innovation
Commissioner Arthur H. Rosenfeld, Ph.DCommissioner Arthur H. Rosenfeld, Ph.DCalifornia Energy CommissionCalifornia Energy Commission
Berkeley Wireless Research CenterBerkeley Wireless Research CenterGranlibakken, CA --- June 1, 2009Granlibakken, CA --- June 1, 2009
Demand Response Event on 7/9/200828 Sites Shed 2.2MW
2
Two Energy Agencies in California
• The California Public Utilities Commission (CPUC) was formed in 1890 to regulate natural monopolies, like railroads, and later electric and gas utilities.
• The California Energy Commission (CEC) was formed in 1974 to regulate the environmental side of energy production and use.
• Now the two agencies work very closely, particularly to delay climate change.
• The Investor-Owned Utilities, under the guidance of the CPUC, spend “Public Goods Charge” money (rate-payer money) to do everything they can that is cost effective to beat existing standards.
• The Publicly-Owned utilities (20% of the power), under loose supervision by the CEC, do the same.
3
California Energy Commission Responsibilities
Both Regulation and R&D
• California Building and Appliance Standards– Started 1977– Updated every few years
• Siting Thermal Power Plants Larger than 50 MW• Forecasting Supply and Demand (electricity and fuels)• Research and Development
– ~ $80 million per year• CPUC & CEC are collaborating to introduce communicating electric
meters and thermostats that are programmable to respond to time-dependent electric tariffs.
4
California’s Energy Action Plan
• California’s Energy Agencies first adopted an Energy Action Plan in 2003. Central to this is the State’s preferred “Loading Order” for resource expansion.
1. Energy efficiency and Demand Response2. Renewable Generation,3. Increased development of affordable & reliable conventional
generation4. Transmission expansion to support all of California’s energy
goals.
• The Energy Action Plan has been updated since 2003 and provides overall policy direction to the various state agencies involved with the energy sectors
5
Per Capita Electricity Sales (not including self-generation)(kWh/person) (2006 to 2008 are forecast data)
0
2,000
4,000
6,000
8,000
10,000
12,000
14,00019
60
1962
1964
1966
1968
1970
1972
1974
1976
1978
1980
1982
1984
1986
1988
1990
1992
1994
1996
1998
2000
2002
2004
2006
2008
United States
California
Per Capita Income in Constant 2000 $1975 2005 % change
US GDP/capita 16,241 31,442 94%Cal GSP/capita 18,760 33,536 79%
2005 Differences = 5,300kWh/yr = $165/capita
6
Annual Energy Savings from Efficiency Programs and Standards
0
5,000
10,000
15,000
20,000
25,000
30,000
35,000
40,000
45,00019
7519
7619
77
1978
1979
1980
1981
1982
1983
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
GW
h/ye
ar
Appliance Standards
Building Standards
Utility Efficiency Programs at a cost of
~1% of electric bill
~15% of Annual Electricity Use in California in 2003
7
8
Impact of Standards on Efficiency of 3 Appliances
Source: S. Nadel, ACEEE,
in ECEEE 2003 Summer Study, www.eceee.org
75%60%
25%20
30
40
50
60
70
80
90
100
110
1972 1974 1976 1978 1980 1982 1984 1986 1988 1990 1992 1994 1996 1998 2000 2002 2004 2006Year
Inde
x (1
972
= 10
0)
Effective Dates of National Standards
=
Effective Dates of State Standards
=
Refrigerators
Central A/C
Gas Furnaces
SEER = 13
9
Source: David Goldstein
New United States Refrigerator Use v. Time and Retail Prices
0
200
400
600
800
1,000
1,200
1,400
1,600
1,800
2,000
1947 1952 1957 1962 1967 1972 1977 1982 1987 1992 1997 2002
Ave
rage
Ann
ual E
nerg
y U
se(k
wh)
or P
rice(
$)
0
5
10
15
20
25
Ref
riger
ator
vol
ume
(cub
ic fe
et)
Energy Use per Refrigerator(kWh/Year)
Refrigerator Size (cubic ft)
Refrigerator Price in 1983 $
$ 1,270
$ 462
~ 1 Ton CO2/year~ 100 gallons Gasoline/year
10
Annual Energy Saved vs. Several Sources of Supply
Energy Saved Refrigerator Stds
renewables
100 Million 1 KW PV systems
conventional hydro
nuclear energy
0
100
200
300
400
500
600
700
800
Bill
ion
kWh/
year
= 80 power plants of 500 MW each
In the United States
11
Value of Energy to be Saved (at 8.5 cents/kWh, retail price) vs. Several Sources of Supply in 2005 (at 3 cents/kWh, wholesale price)
Energy Saved Refrigerator Stds
renewables
100 Million 1 KW PV systems
conventional hydro
nuclear energy
0
5
10
15
20
25
Bill
ion
$ (U
S)/y
ear i
n 20
05In the United States
12
Air Conditioning Energy Use in Single Family Homes in PG&E The effect of AC Standards (SEER) and Title 24 standards
0
500
1,000
1,500
2,000
2,500
3,000
3,500
4,000
1975 1980 1985 1990 1995 2000 2005 2010 2015
Ann
ual k
Wh
per n
ew h
ome
for c
entr
al A
C
If only increases in house size -- no efficiency gainsChange due to SEER improvementsSEER plus Title 24
13
0
20
40
60
80
100
120
3 Gorges三峡 Refrigerators冰箱
Air Conditioners 空调
TWh
2000 Stds
2000 Stds
2005 Stds
2005 Stds
If Energy Star
If Energy Star
TWH
/Yea
r
1.5
4.5
6.0
3.0
7.5
Valu
e (b
illio
n $/
year
)
Comparison of 3 Gorges to Refrigerator and AC Efficiency Improvements
Savings calculated 10 years after standard takes effect. Calculations provided by David Fridley, LBNL
Value of TWh
3 Gorges三峡
Refrigerators 冰箱
Air Conditioners空调
Wholesale (3 Gorges) at 3.6 c/kWh
Retail (AC + Ref) at 7.2 c/kWh
三峡电量与电冰箱、空调能效对比
标准生效后, 10年节约电量 14
Annual Energy Savings from Efficiency Programs and Standards
0
5,000
10,000
15,000
20,000
25,000
30,000
35,000
40,000
45,00019
7519
7619
77
1978
1979
1980
1981
1982
1983
1984
1985
1986
1987
1988
1989
1990
1991
1992
1993
1994
1995
1996
1997
1998
1999
2000
2001
2002
2003
GW
h/ye
ar
Appliance Standards
Building Standards
Utility Efficiency Programs at a cost of
~1% of electric bill
~15% of Annual Electricity Use in California in 2003
15
California IOU’s Investment in Energy Efficiency
$0
$100
$200
$300
$400
$500
$600
$700
$800
$900
$1,00019
76
1978
1980
1982
1984
1986
1988
1990
1992
1994
1996
1998
2000
2002
2004
2006
2008
2010
2012
Mill
ions
of $
2002
per
Yea
r
Forecast
Profits decoupled from sales
Performance Incentives
Market Restructuring
Crisis
IRP2% of 2004
IOU Electric Revenues
Public Goods Charges
16
Demand Response
In 3 cool seasons CA peak is 40 GW, but a/c adds 20 GW in summerSo we want demand response to price. So all customers will receive Communicating interval meters, 10 million of them Dynamic pricing: TOU summer afternoon + “critical peak” 10 days/yr Programmable communicating thermostats and controls. Cost premiums are small: $20-30 for meters, $20-30 for thermostats
TOU and dynamic pricing will change the design of buildings – promote thermal storage and the use of thermal mass, white roofs, etc. If you announce dynamic prices today, architects will design better buildings tomorrow.
17
18
California is VERY MUCH a Summer Peaking Area
California Daily Peak Loads -- 2006
0
10,000
20,000
30,000
40,000
50,000
60,000
70,000
Jan-06 Mar-06 May-06 Jul-06 Sep-06 Nov-06
MW
Residential Air Conditioning
Commercial Air Conditioning
19
Critical Peak Pricing (CPP)with additional curtailment option
0
10
20
30
40
50
60
70
80
Pric
e (c
ents
/kW
h)
Standard TOUCritical Peak PriceStandard Rate
Sunday Monday Tuesday Wednesday Thursday Friday Saturday
Extraordinary Curtailment Signal, < once per year
CPP Price Signal10x per year
?
Potential Annual Customer Savings: 10 afternoons x 4 hours x 1kw = 40 kWh at 70 cents/kWh = ~$30/year
20
Just some of the proposed systems for PCTs and demand response in the residential and small commercial/industrial sectors.
Source: Pat McAuliffe, [email protected]
Possible Strategies to Reduce Electricity Sector Carbon Emissions in California, ignoring ramp up times and other implementation issues -- The ELECTRICITY Perspective
240,000
260,000
280,000
300,000
320,000
340,000
360,000
1990 1992 1994 1996 1998 2000 2002 2004 2006 2008 2010 2012 2014 2016 2018 2020
GW
H
Triple EE Programs
Doubling Standards
20% Renewables
More Efficient Combustion
Less or Cleaner Coal
21
Source: Pat McAuliffe, [email protected]
75
85
95
105
115
125
135
1990 1992 1994 1996 1998 2000 2002 2004 2006 2008 2010 2012 2014 2016 2018 2020
Mill
ion
Met
ric T
ons
of C
O2
eq.
Triple EE Programs
Doubling Standards
20% Renewables
More Efficient Combustion
Less or Cleaner Coal
Possible Strategies to Reduce Electricity Sector Carbon Emissions in California, ignoring ramp up times and other implementation issues -- The CARBON Perspective
22
Load Management Standards
“Cost effective programs that result in improved utility system efficiency, reduced need for new electricity generation, reduced fuel consumption, and lower long-term economic and environmental costs.”
23
Current LMS Proceeding(08-DR-01)
• Assess which rates, tariffs, equipment, software, protocols, and other measures would be most effective in achieving demand response, and
• Adopt regulations and take other appropriate actions to achieve a price responsive electricity market.
24
Proceeding History (08-DR-01)
• IEPR 2007: Proceeding Recommendation– Coordinated with CPUC & ISO
• January 2008: OII/IOR 08-DR-01• March 2 – July 10, 2008: LMS Workshops
– Scoping, Smart Grid, Advanced Metering Infrastructure, Rates, Technology, and Education
• November 2008: Draft Proposed LMS• December 10, 2008: Draft LMS Workshop• January 2009: All Comments in on Draft• January – March 2009: Stakeholder Meetings
25
Successful Statewide DR Requires:
• Advanced Metering Infrastructure (AMI)• Time-Varying and Dynamic Rates• Information Model • Common Signaling Infrastructure (CSI)• Programmable Communicating Devices
(PCDs)
26
“Programs” vs. Direct Demand Response
• Historically, utilities have offered special programs geared toward direct control of loads
• Direct Demand Response takes place without the need to sign up for any special program
27
Load Management Standards Guidelines
1. Customers should determine which loads are shed first
2. Demand Response capability should be available to every customer in the state
3. Customers should not have to participate in utility DR programs
4. Standards should not hinder customer participation in utility DR programs
28
Load Management Standards Guidelines (con’t)
5. Standards should leverage market forces and economies of scale
6. Standards should be technology neutral7. Standards should set minimum technology
functional requirements; e.g. an expansion port on every appliance or an override button for thermostats
8. Customers should have no-cost access to “near-real time” information
29
Proposed Load Management Standards
• LMS -1: Advanced Metering Infrastructure (AMI) Schedule– Purpose: To require all utilities to prepare a plan for
deploying advanced meters to all customers within their service territory.
• LMS-2: Dynamic Electricity Rates– Purpose: To require utilities to develop and offer rate
designs that support the state’s objectives of providing cost-based price signals.
30
Proposed Load Management Standards
• LMS-3: Statewide Time-Differentiated Rate Broadcast– Purpose: To establish a standard method for
transmitting current rate and reliability information to customers.
• LMS-4: Home Energy Rating System Information– Purpose: To require utilities to provide their
customers with information about the Home Energy Rating System, designed to promote the use of in-home energy audits and subsequent cost effective energy efficiency improvements.
31
Proposed Load Management Standards
• LMS-5: Existing Building Peak Energy Efficiency Improvements– Purpose: To require utilities to develop and expand
programs to encourage cost effective energy efficiency improvements in existing building stock within their service territory.
• LMS-6: Programmable Communicating Device (PCD) Program– Purpose: To require utilities to offer a discounted
programmable communicating devices (PCD’s) to customers equipped with advanced meters.
32
Proposed Load Management Standards
• LMS-7: Customer Access to Meter Data– Purpose: To ensure customers have access to
information related to their energy usage on a “near real time” basis.
33
LMS Will Spur Innovation
• Goal #1: Actionable information from interval meters should be available on any display device from any physical channel and device, e.g., via cell phones, broadcast digital radio (RDS) and TV (DTV), the Internet, etc.
• Goal #2: Time-differentiated energy prices create a need for products that automatically act as an energy management proxy to meet individual consumer preferences.
34
LMS Will Spur Innovation
• Goal #3: Traditional consumer devices such as thermostats and appliances will need to “hear” price and grid-event information from utilities and third parties through a variety of physical channels and merge that information with consumer preferences, local weather, existing personal schedules, existing sensors from security & other systems that may come from local sources, from the web, and will be continuously changing.
35
LMS Will Spur Innovation
• Goal #4: Appliances, thermostats, etc., can’t be stranded as technology changes. Simple pathways must be found to upgrade these devices through low-technology actions such as the standard information port being promoted by the U-SNAP Alliance.
• http://www.usnap.org/U-SNAPOverview.pdf
36
U-SNAP Alliance
37
LMS Will Spur Innovation
• Goal#5: Appliances, thermostats, etc., must be able to move to new locations with their owners and still receive price and event information from their new utility and/or third-party providers (Common Information Model).
• Goal #6: Time-differentiated prices will create a need for products that automatically act as energy management proxies for consumers.
38
Wireless Can Help
• Energy-related communications installations must be simple, low cost & low-energy/power– Ad hoc self-organizing networks (no manuals)– Energy/power scavenged from environment
• Must interface & leverage legacy networks, e.g., security, entertainment, home LAN, …
• Must facilitate “operational efficiency” through the seamless exchange of information from all local and global network resources
39