Title: Latest Developments in Dynamic Pricing and Advanced Metering Adoption Restructuring Roundtable
1Latest Developments in Dynamic Pricing and
Advanced Metering AdoptionRestructuring
Roundtable 99February 9, 2007
- Stephen S. George, Ph.D.
- Principal Consultant
- Freeman, Sullivan Co.
2There is so much going on, its hard to know
where to start
- Pricing experiments continue to show that
customers can and will respond to dynamic prices - Combining enabling technology with price signals
significantly increases demand response - Getting customers to try time-varying rates
remains a challenge - Information feedback is showing promise
- Unfortunately, its still true that if you ask
two people what AMI is, youll get three answers - Open standards (at least half open) are the
newest in thing - EPAct continues to generate a lot of heat for DR
and AMI (but how much light remains to be seen) - PPL takes the plunge into the world of MDM
- California continues to build DR infrastructure
3As the results of each new pricing pilot become
available, a common story is developing
Price Ratio 4.11 41
4.61
4More experimental results are on the way?
- Analysis from PSEGs pricing pilot should be
available within the next few weeks - Xcel Energys pricing pilot is complete and a
regulatory filing is due in April - The regulatory log-jam that stalled the Pepco
(SMPPI) pricing pilot finally broke earlier this
month - Will examine CPP and Peak Time Rebates
side-by-side - Results are a year away
- Similar results are being seen across a wide
spectrum of pricing concepts - CPP, RTP and PTR (rebates)
There is 30 years of research indicating that
mass-market customers can and will respond to
time-varying price signalsis it time to stop
doing experiments and just get on with it?
5Combining price signals with control technology
significantly increases demand response
- Californias Statewide Pricing Pilot showed
- That peak-period impacts on critical days roughly
doubled for residential customers when PCTs were
used - For CI customers with demands less than 20 kW,
there was no reduction on critical days without
PCTs but a 13 reduction with PCTs - For CI customers with demands between 20 and 200
kW, there was a 5 reduction without PCTs and a
10 reduction with PCTs - In the Ameren pilot, reductions doubled with PCTs
for residential consumers - The Gulf Power program is the poster child for
enabling technology combined with dynamic pricing - But Gulf Powers population characteristics
differ significantly from consumers in most other
parts of the country
6The real challenge is getting customers to try
time-varying prices
- Market research and experience indicate that
customers are reluctant to sign up for CPP
tariffs due to risk aversion - Customers like time-varying rates once they try
them, but when considering whether or not to sign
up, customers focus more on down-side risk than
upside potential - There is no political will to place customers on
default dynamic rates - Massachusetts examination of this is encouraging
and CA keeps talking about it - SDGEs proposal for a carrot-only peak time
rebate offering addresses the downside risk and
may prove popular - UC Energy Institute has proposed a new Incentive
Preserving Rebate tariff that addresses
psychological barriers to acceptance - PGEs AMI application proposed an aggressive
marketing campaign to attract 30 of its target
population for CPP rates - CAs aggressive approach with enabling technology
could help
7Information feedback is gaining attention
- Hydro Ones experiment was the first
statistically rigorous study of the impact of
real-time information feedback on energy use - More about energy conservation than demand
response - Roughly 400 customers monitored over 2.5 years
- Provided with usage, dollar and CO2 emissions per
hour, total to date and predicted - 6.5 average reduction across all households
- Reductions were lowest for households with
electric space heating (1.2) and highest for
households with electric water heating but no
electric space heating (16.7) - Salt River Project has conducted a similar pilot
8What is advanced metering infrastructure?
- Advanced metering is a metering system that
records customer consumption and possibly other
parameters hourly or more frequently and that
provides for daily or more frequent transmittal
of measurements over a communication network to a
central collection point. - (FERC, Assessment of Demand Response Advanced
Metering, August 2006) - Most people would agree that this definition
identifies the minimum functionality of
AMIinterval data daily - Others (DRAM, CPUC) include much greater
functionality, including two-way communication,
remote connect/disconnect, information provision
to consumers, and interface with end-use control
devices
9What advanced metering is not!
- Mobile AMR ? AMI
- And a movement to legislate accelerated
depreciation for AMI that includes mobile AMR
for monthly collection of TOU data will hinder
demand response penetration - Indeed, any investment in mobile AMR will hinder
DR penetration for years to come - Fixed-network AMR ? AMI
- While defining AMI correctly, FERCs survey
counted every fixed-network AMR system as AMI - Substantial investments and/or additional
outsourcing payments would be required to obtain
interval data on a large number of customers from
many legacy fixed network AMR systems - PPLs system is the ONLY one that currently
gathers hourly data on all customers (once
installed, PGEs system will do so, as will
Edisons and SDGEs if approved)
10Open standards are all the buzz
- OpenAMI, Grid Wise, Intelligrid, SCEs functional
specification, etc. - There are many organizations touting the benefits
of open communication protocols between an AMI
system and end-use devices - Eventually, this could allow consumers to
purchase compatible control and display devices
at Home Depot for example and foster competition
among suppliers - SCE is requiring AMI suppliers to have Zigbee
compatible meter communication capability - Itron and DCSI (and perhaps others) are going to
market with offerings that meet this requirement
11EPAct is generating a lot of heat (but how much
light?)
12PPL takes the next step
- PPL is the only utility that currently collects
hourly data on all of its customers - But until recently, that data was being discarded
- PPLs AMI system was estimated to be essentially
breakeven based solely on operational savingsDR
was not directly considered - PPL recently completed initial installation of
Nexus MDM - Energy Visionenterprise-facing software that
manages usage data in order to improve business
processes such as billing, forecasting,
settlement, revenue protection and distribution
planning - Energy Prisma customer-facing application that
provides customers with more useful information
on bills or through web-based interfaces. - PPL has high hopes that the self-service aspects
of a web portal will lower costs, improve
customer service and foster better consumer
decisions
13Web portals can provide valuable information
Links to additional content and tools
Peak energy is expensive- Use it Wisely
Save money by using less peak energy, especially
on Critical Peak days
How do I spend my energy dollars during Peak
Periods?
Take action, especially on Critical Peak days
14A load shift calculator can help customers decide
what actions to take to shift load
15CA is developing the most DR friendly
infrastructure in North America
- The CPUC approved PGEs AMI application in June
2006 - PVRR of 2.2b to replace 5 million electric
meters (PLC by DCSI) and 4 million gas meters
(RF by Hexagram) - Deployment will be complete by the end of 2010
- SDGEs AMI application is being reviewed and a
decision is expected this quarter - Settlement discussions currently underway with
interveners - SCEs RFP is currently on the street
- The CEC has proposed to modify building standards
so that all new construction and all HVAC
retrofits will have PCTs - PCTs will have one-way radio or paging capability
(with no override) to be used for reliability and
a port through which Zigbee or other protocols
can be incorporated for use by utilities for
economic dispatch
16At PGE, operational savings covered 90 of
costs demand response easily covered the gap
460
Demand Response
2500
2,227
200
2.026
Gap
2000
1500
Millions of Dollars
Operational Benefits (PVRR)
Costs (PVRR)
1000
500
0
17At SDGE, operational savings only covered 60 of
costs. An aggressive DR strategy covered the gap
18Key Conclusions
- Customers can and will respond to time-varying
prices - Responsiveness seems to be similar across
alternative rate concepts (CPP, RTP, PTR) and
across utilities (after adjusting for population
characteristics) - Getting customers to try time-varying rates can
be difficult - But once they do, they often embrace these
options - Risk aversion is a significant barrier that
carrot-only approaches and enabling technology
can help address - Enabling technology such as programmable
communicating thermostats can significantly
increase demand response - And may be essential for small CI customers
19Key conclusions (continued)
- AMI functionality continues to evolve rapidly
- Open standards for beyond-the meter control and
information technology will help drive down costs
and increase penetration - MDM functionality is also evolving
- In-home displays, web portals and enhanced bill
presentment can improve customer decisions - Demand response is rapidly becoming the hot
topic at both the state and federal level and a
key driver of interest in AMI - The combination of pricing, enabling technology
and enhanced information, built on an AMI
platform, can produce substantial demand response
20For more information, contact
- Dr. Stephen S. George
- Principal Consultant
- Freeman, Sullivan Co.
- 415 777-0707
- StephenGeorge_at_FSCGroup.com