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Customer Services and the Changing
Needs of the CA Electricity Grid
Stanford University May 5, 2015
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Agenda
• Overview of DR
• CA Energy Policy
• DR in CA
• Other Markets
• System Needs
• Regional Resource Sharing?
• Questions
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About EnerNOC-
Energy Intelligence Software
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Indiana, Michigan
AEP I&M
EnerNOC’s North American Demand Response Footprint
New York
Consolidated Edison
New York ISO
Mid-Atlantic, Virginia,
West Virginia, North
Carolina, Ohio, Illinois,
Indiana, Michigan
PJM Interconnection
Florida
Tampa Electric Company
(TECO)
Kentucky, Tennessee,
Georgia, Alabama,
Mississippi
Tennessee Valley
Authority (TVA)
Louisville Gas & Electric
and Kentucky Utilities
(LG&E and KU)
Texas
Electric
Reliability
Council of
Texas (ERCOT)
New Mexico
Public Service
Company of New
Mexico (PNM)
Arizona
Tucson Electric Power
California
Pacific Gas and
Electric (PG&E)
Southern California
Edison (SCE)
Utah and Idaho
Pacificorp
Oregon
Portland General Electric
(PGE)
Colorado
Xcel Energy
Alberta, Canada
Alberta Electric System
Operator (AESO)
Idaho
Idaho Power Company
Kansas
Midwest Energy
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EnerNOC Acquisitions Energy Intelligence Software and International Growth
Commercial Customer Engagement
Pulse Energy
International Demand Response
Entelios AG
Activation Energy
Energy Procurement & Management
Entech USB
World Energy Solutions
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A Global Demand Response Footprint
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• We meet you where you operate – in 104 countries
Global Capability
Supporting 15
languages
Managing one million
bills annually
Worldwide currencies
and measurements
Countries Covered
Global offices in
12 countries
Streaming data from over
14,000 enterprise sites
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Comprehensive Utility EIS Solutions A single platform to serve all C&I customers, large and small, with 50+ utility partners globally
Customer Engagement
Engage customers through
customized, timely, and
valuable content
Demand Response
Transform customers into a
virtual power plant; create
value added services and a
tool for traders
Operational Effectiveness and Customer Management
Targeted program design, smarter marketing, seamless customer service
Energy Efficiency
Provide actionable insights
delivered to customers and
improved energy efficiency
program adoption
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9 Proprietary and Confidential
About EnerNOC
Proven Customer Track
Record • Thousands of enterprise
customers across over 35,000
sites
• $1B in customer savings
delivered to date
• Market leader in demand
response
To learn more, visit http://www.enernoc.com
Strong Financial Profile
• 2014 Revenues: $472M
• 2014 Adjusted EBITDA: $76.4M
• $246M in cash/cash equivalents on
balance sheet
• Publicly traded on the NASDAQ)
(ENOC)
• Over 1,000 employees and growing
fast; multiple “top places to work”
awards
Full Value and Technology
Offering
• Energy intelligence software = ~$5B
market in U.S. alone
• Energy intelligence application
platform addresses demand and
supply-side, connects energy usage
to currency
• Combines technology, managed
services, and market access
• ~$200M invested to date in
technology
Updated 2 2015
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CA Energy Policy
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CA EPA
CARB
FERC CAISO
IEPR LTPP
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12 Proprietary and Confidential
NOW: Governor & Legislature
• Governor issues Executive Order to achieve GHG emissions reductions equal to 40% below 1990 levels by 2030. (April 2015)
• Governor describes energy policy vision in inaugural address (January 2015) • Increase electricity generation from renewable sources by 50% by 2030. • Increase energy efficiency in existing commercial building by 50% by 2030. •Decrease petroleum use in the transportation sector by 50% by 2030.
• SB 350 (De Leon)-codifies the Governor’s Inaugural Goals.
• SB 32 (Pavley)-directs CARB to establish new GHG emissions reduction targets for 2030 and 2040.
• SB 286 (Hertzberg)-lifts direct access suspension by 1/3 over 3 years with increased RPS requirement.
• AB 793 (Quirk)-incentivizes energy management technology adoption for residential and business customers.
• AB 1330 (Bloom)-establishes an EE and DR procurement standard.
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13 Proprietary and Confidential
Main Drivers for Energy Policy
• Greenhouse Gas Emissions Reductions • Renewable Resources
• EE & DR
• Electrification of the transportation sector
• Increased penetration of distributed energy resources
• Increased Customer Participation • AMI
• Data Access/Privacy
• Reliability
• Meeting changing system needs (ramping)
• Better integration of resources
• SONGS replacement
• Water/Energy Nexus • Drought
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DR in CA
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15 Proprietary and Confidential
Demand Response and Energy Efficiency
• Long History of EE and DR programs
• Joint Energy Agencies’ Energy Action Plan (2003, 2005, 2008) • Establishes a loading order or preferred resources
• EE and DR, Renewable Resources and Distributed Generation
• Third party programs promoted in 2007
• Legislation requires electrical corporation to procure all “cost-effective, feasible and reliable DR and EE.
• DR and EE planning has happened outside of other procurement planning • Until SONGS closure and SCE LCR RFO (2014)
• Commission adopts a policy to “bifurcate” DR (2014) • Supply-Side Resource
• Load Modifying Resource
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16 Proprietary and Confidential
Import of Being Either a SS or LMR DR Resource
• SS DR RECOGNIZED AS A RESOURCE BY CAISO FOR PLANNING PURPOSES
• LOAD MODIFYING RESOURCES WILL ADJUST THE DEMAND FORECAST
• NOT CLEAR HOW ALL OF THE VALUE OF A LOAD MODIFYING RESOURCE WILL BE RECOGNIZED • If adjust actual monthly or annual peak •Hard triggers •Not clear if supply-side resources will have a premium over LMRs •Not clear how flexible capabilities will be recognized
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17 Proprietary and Confidential
Supply-Side DR
• Participate in CAISO’s energy and/or ancillary services market • Meet resource adequacy for system and local reliability purposes (Reliability Services
Initiative) • Approved by the Board of Governors • Will be Submitted to FERC
• Meet flexible resource adequacy requirements (approved by FERC)
• Must-Offer Requirement in the day-ahead and/or real-time energy markets
• CPUC is testing a DR Auction Mechanism (DRAM) • Third-party DRPs meet CAISO’s resource adequacy requirements in exchange for a capacity payment
• Winning bidder must meet system RA requirements and Rule 24 requirements for participating in the wholesale market with retail customers
• First auction held in late summer/early fall 2015; delivery in June-December 2016
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18 Proprietary and Confidential
SCE and PG&E Rule 24, SDG&E Rule 32
• IOU Tariff that establishes the responsibilities between the IOU/LSE and the Demand Response Provider (DRP) • Customer authorization for release of customer data
• Requirement that a DRP cannot register a customer to participate in the wholesale market who is participating in a utility retail DR program
• Requirement for the DRP/IOU to sign an agreement to abide by Rule 24
• Requirement for the DRP to register with the CPUC
• Requirement for the DRP to follow consumer protections
• Requirement for the DRP to pay applicable charges to the IOU
• Requirement for the IOU to provide timely access to data for settlement purposes
• Requirement for the DRP to sign the CAISO/DRP Agreement, requiring the DRP to abide by CAISO’s Tariff
• Requirement for the DRP to become or retain a scheduling coordinator for purposes of bidding or scheduling into the CAISO’s energy and ancillary services market
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Why Hasn’t DR Participated in the CAISO Before Now? Controversy over FERC Order 745
DR= generation
• FERC Order 719 (2008)
• FERC Order 719-A (2009)
LMP if provides net benefit
• FERC Order 745 (2011)
• FERC Order 745-A (2011)
CPUC Suspension
Rule 24 Developed
• EPSA Challenge to DC Circuit
• DC Circuit overturns Order 745
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Can prices drive the needed
response?
• Don’t chase ISO markets just because we can • Look ahead to services we need going forward • Eric Cutter, E3 Presentation 10/16/13 CPUC DR Rulemaking Workshop
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Other Markets
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22 Proprietary and Confidential
PJM Screen Shot for BGE Zone
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24 Proprietary and Confidential
ISO-NE Screen Shot 7-22-11
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25 Proprietary and Confidential
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System Needs
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Conventional resources will be dispatched to
the net load demand curve – High Load Case
Lo
ad
& N
et L
oa
d (
MW
)
0
1,000
2,000
3,000
4,000
5,000
6,000
7,000
8,000
9,000
10,000
20,000
22,000
24,000
26,000
28,000
30,000
32,000
34,000
36,000
38,000
40,000
42,000
44,000
46,000
0:00 1:30 3:00 4:30 6:00 7:30 9:00 10:30 12:00 13:30 15:00 16:30 18:00 19:30 21:00 22:30 0:00
Load Net Load Wind Solar
Load, Wind & Solar Profiles – High Load Case
January 2020
Win
d &
So
lar
(MW
)
8,000 MW
in 2 hours
6,300 MW
in 2 hours
13,500 MW
in 2 hours
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Advanced DR Scenario Looking at the ability to increase and decrease load throughout the day.
Source: Investigating a Higher Renewables Portfolio Standard in California, Energy and Environmental Economics, Inc, January 2014, page 122
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CAISO Market Notice
• Market Notice • April 30, 2015
•
•
• Categories
• Grid Operation
• Market Operations
•
•
• Notification of Ancillary Services Scarcity Event 4/21/15 • •
• Summary
• Ancillary services scarcity pricing was triggered on April 21, 2015 in the 15-minute market run.
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Examples of Fast Response DR
Pilots for BPA, including
load-following projects Synchronized Reserves
Market requires 10-minute
response; many assets are
automated AutoDR demonstration for
commercial customers
Many assets automated to
provide 10 min response;
qualifies at WECC non-
spinning reserves
DR program
implemented to
accelerate adoption of
existing DR tariff
Funding available for
AutoDR technology to
accelerate growth in
existing DR programs
AutoDR with a UFR that
responds to changes in
frequency in 0.2 second
Direct load control
programs with automation
for all customer classes
AutoDR resource providing
ancillary services with <1 second
response time
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Balancing Both Spikes and Dips in Demand
Case Study: Bonneville Power Administration (BPA) Wind Integration Pilot
Pilot Background
• Pace of wind power development in the Pacific
Northwest is exceeding BPA’s expectations
• BPA has 3,000 MW of wind interconnected today, with
6,000 MW of requests ‘in-process’ and another
15,000 MW of requests ‘in-discussion’
• Given that BPA has a total of 40,500 MW of capacity,
this is dramatic penetration for the region
Pilot Parameters
• Direct load control, although customer will have
manual override capability, as well as the ability to set
specific temperature boundaries
• Loads controlled both up and down
• 24/7/365 resource availability
• Dispatch upon 10 minutes notice
• Maximum 30 minutes per event and 2 events per day
• Minimum 3 hours between events
• Other event limitations may be employed, subject to
customer and utility needs
EnerNOC is helping BPA use aggregated C&I end-use loads to
providing a load following resource to mitigate the intermittency of
wind power
Copyright 2013 - EnerNOC, Inc.
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The need DR as a grid-balancing ancillary service
European markets have unique requirements
• Increasing shares of fluctuating renewable energy resources create the need for flexible capacity to
balance the grid.
• Intelligent aggregation (pooling) of individual demand-side flexible assets provide this reliable source
of capacity.
European Transmission System
Operators (TSOs) increasingly
welcome the participation of DR
as a grid-balancing ancillary
service in their reserve programs
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Program types Criteria for ancillary services
Amprion’s Secondary Reserve Program had originally been
designed for participation of generation assets.
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Regional Cooperation?
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EPA
• RICE NESHAP-allows BUGs for emergencies
•Overturned by DC Circuit
• MATS-Coal Retirements •Challenged and upheld
• Clean Air Act Section 111(d) •Final Rule Issued by June 30, 2015
•Compliance by June 30, 2016 (with ability to extend for •one or two years)
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• Flexible capacity is one of several operational changes that need to be
adopted to efficiently integrate renewable resources
•Expanded balancing area cooperation, including dynamic transfers
•Expand sub-hour dispatch and Intra-hour scheduling
• Improved forecasting of wind and solar
•Commit additional operating reserves
•Build or increase utilization of transmission
•Target new or existing DR to assist with variability
• “It is more cost-effective to have demand response address the 89 hours of contingency reserve shortfalls rather than increase spin for 8760 hours of the year. Demand response can save up to $600M/yr ($510M/yr in 2009$) in operating costs versus committing additional spinning reserves.” NREL WWSIS at p. 22
Studies on Operational Impacts of Renewable
Integration
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ISO to add Puget Sound
Energy to the Energy
Imbalance Market PSE to
join ISO, PacifiCorp and
NV Energy to find mutual
savings for their
consumers
Benefits top $11m since start of ISO’s Energy Imbalance Market
APS: the Company believes that it is in the best
interests of customers to participate in the EIM.
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38 Proprietary and Confidential
CAP & TRADE
• California and Quebec sign agreement to integrate, harmonize their cap-and-trade programs
• Is Ontario Next?
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39
Take Aways
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40 Proprietary and Confidential
What is Ahead?
• CA will continue to lead on GHG reduction policy
• Need agreement across the state as to what our energy priorities are
• That policy will open new opportunities for distributed energy resources
• State regulatory policy and the ways in which we plan for resources will also change
• It is necessary for resources to be integrated with system needs
• Need to incorporate customers in ways they have never been before
• If EPA policies stand, the rest of the nation will be changing as well
• Important to seek regional cooperation
• WE CAN DO THIS!
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Questions?
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Mona Tierney-Lloyd, Sr. Director
415.238.3788
www.enernoc.com