intelligent load management in the long term energy plan
DESCRIPTION
Paul Grod together with the ILM Task Force met with Minister of Energy Bob Chiarelli to discuss Ontario’s Long Term Energy Plan and the role of demand response.TRANSCRIPT
Presentation to the Minister of Energy
by the ILM Task Force, Ontario Energy Association
October 2, 2013
By Ron Dizy, Enbala (Chair),
Paul Grod, Rodan Energy (Vice Chair)
and Herb Healy, EnerNOC
Agenda
ILM Task Force
What is ILM?
Why is it germane to the LTEP?
What services can ILM provide?
What is ILM’s relative value? Some practical examples
What steps should be taken to better reflect ILM in the LTEP?
ILM Task Force Members
AMPCO – Adam White Canadian Manufacturers and
Exporters Association – Ian Howcroft and Paul Clipsham
ENBALA – Ron Dizy (Chair) and Keyvna Cohanim
Energate – Alan Clarke EnerNOC – Herb Healy IESO – Mark Wilson LocalGrid Technologies – Bob Leigh MaRS – Jesika Briones, Jon
Dogterom
Ministry of Energy – Paul Kersman and Mike Smith
OEA – Avi Lipsitz
OEB – Takis Plagiannakos
Office of the Minister of Energy - Chris Wray
OPA – Evelyn Lundhild and Julia McNally
PowerStream – Martin Rovers, John Mulrooney
Rodan Energy – Paul Grod (Vice-chair) and Paul Shervill
Siemens – Richard Wunderlich (Vice-chair) and Darryl Johnstone
Union Gas – Ed Seaward
John Lambert, Independent Consultant
What is ILM?
ILM (Intelligent Load Management) enables system operators and utilities to control how much and when power is consumed from the grid
Provides a new, highly cost effective tool to more efficiently operate the grid Shaves peaks and fills valleys in the power curve
Enhances reliability – local or province-wide – e.g. 100MW of local relief during Toronto power outage
Delivers Operational Flexibility
Economic value – reduces overall cost, enhances asset life, reduces need to overbuild costly infrastructure
What is ILM?
ILM is distinct from conservation and energy efficiency - conservation and energy efficiency refer to “using less” on a continuous basis whileILM is a targeted, dispatchable system resource
Conservation
CDMDR
Flexibility
ILM
Energy
Efficiency
Intelligent
Load
Management
TodayTarget
What is ILM?
ILM refers to a family of demand response
products which include:
Peak load management - to reduce peak demand at
critical times through curtailment or time shifting
Regulation - to assist system operators with minute by
minute adjustments to the grid
Ramp - a resource which fills-in while generators are
coming up to full power
Balancing - clean cost effective hedge when intermittent
wind or solar output is not available
Reserve margin - to help meet reliability requirements
Surplus base-load generation -– soak up excess power
produced by inflexible generation
Higher Wind and Solar
increases Net Load
ramp by 100-400 MW
ILM fills-in while generators are
coming up to full power
Source - IESO Stakeholder Summit -
March 4, 2013
ILM can address
surplus generation
2000MW of DR to
reduce infrastructure
overbuild
Why ILM is germane to the LTEP?
Several system changes have been made in recent years which system operators must accommodate: Changing supply mix -
coal phase out more renewable (wind, solar) generation added more natural gas nuclear refurbishment
Smart grid advancements – smarter networks opportunities for greater participation by loads advancements in real time load control
The value of ILM ILM products can provide capacity, operational
flexibility and help defer the need for capital expenditures at both the transmission and distribution levels
ILM products: less expensive and cleaner than many traditional
solutions
in combination with generation solutions optimizes operation of the system
promotes customer engagement
enhances power system efficiency
ILM is cost effective
Source: DR-OPA. DR3 Program Rates – range from $65,000 to $100,000/MW/year (100 hour program) Gas Peaker Plant – US Energy Information Administration. www.eia.gov/forecast/capitalcost. Based on conventional combined cycle plant cost ranges between $170,000 + $210,000/MW/year.
$190,000 /MW/year
$85,000/MW/year
0
50,000
100,000
150,000
200,000
Gas Peaker Plant Demand Response
$/M
W/y
ear
Adjusting Dispatch Stack to Supply Flexibility
Level of Demand
In order to provide necessary flexibility we must:
•Request nuclear maneuver
•Curtail wind
•Run a gas generator at 300 MW minimum
Implications:
•Paying nuclear (and wind) for energy we don’t use
•Paying gas unit to be on, when we don’t require its energy
•EQUALS – VERY EXPENSIVE WAY TO PROCURE FLEXIBILITYNuclear
Must Run Hydro
Wind
MW
Nuclear
Nuclear Maneuver
Must Run Hydro
Wind
Gas Generation
MW
Wind Maneuver
Some ILM examples
Northern York Region: York Energy Center 400MW simple cycle plant was built in
2012
Prior to construction, a 20 MW demand response resource was not permitted to grow and was terminated in favour of a peaking generator
Estimated DR capacity for York Region is 50MW
Maintaining and growing the DR capacity and reducing the size of the peaking generator accordingly could have saved ratepayers approximately $100,000/MW/year.
Would have meant net savings of ~$5M/year
Some ILM examplesDR and EE save PJM Ratepayers $11.8B in 2013/14
“Based on actual auction clearing prices and quantities and the make-whole MW, total RPM market revenues for the 2013/2014 delivery year were $6,708,567,045. If no DR or EE had been offered into the auction, total RPM market revenues for the 2013/2014 delivery year would have been $18,535,847,876, a difference of $11,827,280,831 compared to the total based on actual results.”
- PJM Market MonitorAnalysis of the 2013/2014 RPM Base Residual Auction Revised and Updated, September 2010
UNITED KINGDOM
National Grid Short Term Operating
Reserves (STOR)
Response time: < 20 minutes
USA: ERCOT
LaaR program for both responsive
reserve and non-spinning
reserves. Instantaneous and 10
minute response.
NORDPOOL
Multinational power exchange provides
Regulation and Spinning Reserves
USA: PJM
Synchronized Reserves and
Regulation programs require 10
minute and 4 second response,
respectively
CANADA
Atlantic Provinces
Fast-acting DR to balance intermittent wind
AESO LssI: Frequency responsive
instantaneous DR resources
GERMANY
The country’s four TSO jointly operate
three A/S markets including “negative”
secondary and tertiary reserves
AUSTRALIA, NEW ZEALAND
Both the NEM and NZEM feature
frequency response markets open
to DR (e.g. FIR/SIR; FCAS)
Some ILM examplesDemand Response provides power grid support around the globe
Source - EnerNOC
Creating a level playing field for DR
DR requires capacity payments (like generation) to be successful
Needs a long term commitment with meaningful financial incentives Today’s 400MW took 6 years of committed development from
aggregators making significant investments in ON
Long term, it should be deployed and utilized based on market mechanisms.
Creating a level playing field for DR
IESO and OPA recognize that DR can play many valuable roles in the power system Shave the peaks and fill the valleys by quickly and cost-
effectively reducing peak consumption and bringing demand “on” when there is surplus generation
There are opportunities to evolve existing unit commitment and other IESO mechanisms to allow DR participation
Capacity payments critical as energy prices are unlikely to ever be sufficient to induce DR (in Ontario the price signals are both suppressed and far too small)
“Programs leading to markets” use significant scale programs to gain experience and then
evolve market rules Provide IESO/OPA authority to procure ILM resources as
required and cost-effective.
Recommendations/next steps to greater ILM use
1. Establish goals for ILM as a distinct resource in the LTEP.2. Maintain momentum and confidence in ILM as a resource.
a) Remove the OPA’s 500MW limit on DR3 to demonstrate continued momentum and commitment to DR as an important system resource.
b) Empower the IESO to dispatch new DR3 and related ILM resources in a new and meaningful way based on IESO market mechanisms.
c) Procure ILM first (provided it is cost-effective) in any regional energy plans.
d) Remove barriers for DR participation (e.g. transmission connected loads cannot participate in DR3; and municipalities cannot use standby generation for peak shaving).
3. Programs leading to markets for new applications. a) Direct the OPA/IESO to engage with stakeholders to expand DR
participation in markets.b) Direct (and fund) the OPA/IESO to engage in programs to gain experience
with highest value ILM applications, leading to market rule changes to support a level playing field for DR.
Q&A
Thank you!