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TRANSCRIPT
CCAP Presentation August 6, 2015
Dhaval Dagli
Principal Manager, Regulatory Policy, Southern California Edison
One of the nation’s largest electric utilities
• Subsidiary of Edison International, a Fortune 500
company
• Investor-owned utility regulated by the California
Public Utilities Commission (CPUC)
• Nearly 14 million residents in service territory
• 5 million customer accounts
• 50,000 square-mile service area
• Approx. 23,000 MW area peak load
• Approx. 89 billion kWh annual energy sales
Significant infrastructure investments
• 1.4 million power poles
• 700,000 transformers
• 103,000 miles of distribution and transmission lines
• 3,100 MW owned generation
Southern California Edison Highlights
Edison Intl. is Responding to Industry Change
• Public policy prioritizing environmental
sustainability
• Innovation facilitating conservation and
self-generation
• Regulation supporting new forms of
competition
• Flattening domestic demand for electricity
• Grid of the future will be more complex and
sophisticated to support increasing use of
distributed resources and transportation
electrification
SCE Strategy
• Invest in, build, and operate the next
generation electric grid
• Operational and service excellence
• Enable California public policies
Edison Intl. Competitive Strategy
• Targeted investments in emerging
technologies and markets to follow
changes in the industry and better
exploit opportunities as they arise
– Commercial and industrial distributed
generation
– Energy optimization
– Energy efficiency and software
– Residential solar industry financial
services and software
– Electric transportation
Long-Term Industry Trends Strategy
SCE’s Guiding Principles
1. Promoting customer choice and customer engagement are key
objectives
2. The distribution grid can play a key role in reducing carbon in California
3. Safety, reliability, and resiliency must remain paramount objectives
4. Costs of electric service must remain affordable and equitably-
apportioned to customers
5. Competitive processes for the selection of resources should be utilized
to the greatest extent possible
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SCE’s Decoupled Regulatory Model
Decoupling of Regulated
Revenues from Sales
Major Balancing Accounts
• Fuel
• Purchased power
• Energy efficiency
• Pension-related
contributions
Advanced Long-Term
Procurement Planning
Forward-looking Ratemaking
• SCE earnings are not affected by changes in retail electricity
sales
• Differences between amounts collected and authorized
levels are either billed or refunded to customers
• Promotes energy conservation
• Stabilizes revenues during economic cycles
• Trigger mechanism for fuel and purchased power
adjustments at 5% variance level
• Utility cost-recovery via balancing accounts represented
more than 55% of 2014 costs
• Sets prudent upfront standards allowing greater certainty of
cost recovery (subject to reasonableness review)
• Three-year rate case cycle
• Separate multi-year cost of capital proceeding
Regulatory Model Key Benefits
California’s Renewables Procurement Standard • On April 12, 2011, Governor Brown signed
into law a 33% Renewables Portfolio Standard (RPS) for California by 2020
– Allows use of Renewable Energy Credits
(RECs) for up to 25% of target with
decreasing percentages over time
– Applies similar RPS rules to all electricity
providers (investor- and publicly-owned
utilities, as well as Electric Service
Providers)
• In order to meet the 33% RPS requirement by 2020, SCE will need to increase its renewable purchases by 7.4 billion kWh per year, or 42%
• Legislative efforts are underway to increase the renewable requirement to 50% by 2030
SCE is on track to meet the 33% renewables target by 2020
Solar 15%
Small Hydro 2%
Geothermal 39% Biomass 2%
Wind 42%
Actual 2014 Renewable Resources:
23.4% of SCE’s portfolio
Distribution Grid of the Future
One-Way Electricity Flow
• System designed to generate
electricity from large central plant
• Very few distributed energy
resources
• Voltage relatively simple to maintain
• Limited situational awareness and
visualization tools for grid operators
Renewable Generation Mandates
Subsidized Residential Solar
Lack of Electric Vehicle Charging
Infrastructure
Variable, Two-Way Electricity Flow
• Distribution system at the center of
the grid
• System designed to serve variable
resources and customer demand
• Digital monitoring and control
devices and advanced
communications systems to manage
two-way flows
• Improved data management and
grid operations with cyber
mitigation
Maximize Distributed Resources and
Electric Vehicle Adoption
• Distribution grid infrastructure
design supports customer choice
and greater resiliency
Current State Future State
Objectives:
• Modernize the distribution system to accommodate customer choice
• Enable new technologies and services that reduce emissions and improve reliability
• Animate opportunities for Distributed Energy Resources (DERs) to realize benefits by providing grid
services
Key Elements:
• Tools for identifying optimal locations for DERs (includes Distributed Generation, energy storage,
Electric Vehicle charging, Energy Efficiency, and Demand Response )
• Modernization of system planning tools, design and operations
• Technology recommendations (information technology, communications, system planning, voltage
and frequency controls, etc.)
• Demonstration projects to test distribution models and technologies
• Investment plans for grid modernization
SCE Distribution Resources Plan (DRP)
New Technology Grid Impacts
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1
3
1
1
1
2
2
Future state based
on evolving energy
landscape
More automated
and digital, with
more sophisticated
voltage control and
protection schemes
Facilitates
increasing
renewables & two-
way power flow
Cyber mitigation
must be included
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2
3
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Capabilities
Expedient Interconnection Processing
Increased Situational Awareness
Accurate Forecasting and
Planning
Investments
Distribution and Substation
Automation
Communications & Interoperability
Technology Platforms and Applications
Enabled By People Strategy Business Processes
• Increased
manpower
• New skill sets
• Training process
• Workforce
Evolution
• Work Management & logistics
• Evaluation of processes for
suitability
• Design Standards moving
forward
• Procurement & Planning
Integration
• Construction and operational
procedures Greater Interaction with and Control of
DERs
Grid Reinforcement
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Grid Modernization Requirements
2015 - 2017 2018 - 2020 2021 +
Implement foundational
information technology,
communication systems, and
system planning tools; begin
grid reinforcement work
Expand automation and
improve communications and
control with Distributed Energy
Resources; continue grid
reinforcement work
Continue grid modernization,
maximize benefits of Distributed
Energy Resources and continue
integrating into planning and
operations Tech
no
log
y
Exp
ect
ed
Resu
lt
GR
C
Cycl
e
Prepare organization
and workforce to
execute incremental
work
Ramp up resources and develop talent pipeline
Compliance, safety, and
reliability; preparation for future
grid state
New business opportunities
enabled; full deployment of grid
modernization
Prepare grid management
systems to handle increased DER
and support more grid
transactions
Peo
ple
an
d
Pro
cess
SCE’s Grid Modernization Road Map
Residential Rate Design • CPUC recently completed a comprehensive review of residential rate structure including a future
transition to time of use rates
• July 2015 CPUC Decision includes:
- Transition to 2 tiered rates by 2019
- “Super User Electric Surcharge” for usage 400% above baseline (~4% of current residential load)
- Continue fixed charge at $0.94/month; allows for consideration of increased fixed charges in
future
- Minimum bills up to $10/month which applies to delivery revenue only
Current Rates – July 2015
17.8¢
39.9¢
100% 101-400% >400%
22.8¢
Usage Level (% of Baseline)
¢/k
Wh
Future Rates - 2019
Usage Level (% of Baseline)
14.9¢
25.4¢ 30.9¢
100% 101- 130%
131- 200%
200-400% >400%
19.3¢ ¢/k
Wh
Fixed Charge: $0.94/month
Minimum Bill: $1.79/month Fixed Charge: $0.94/month
Minimum Bill: $10.00/month
Note: Graphs not to scale. 2019 rate levels are based on current revenue requirements
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NEM Program Eligibility: • Technologies up to 1MW, sized to
annual onsite load • Program ends July 1, 2017
NEM customers still pay: • Residential / Small Commercial
o Non-energy charges monthly (minimal)
o Energy charges annually • Commercial
o All charges monthly (energy, non-energy, demand)
NEM customers do not pay: • T&D costs billed volumetrically • Interconnection application fees • Study fees • Distribution upgrade costs • Standby charges • Departing load charges
SCE meter records the
energy supplied by SCE from the
grid
SCE meter records energy produced by the customer that is exported to the grid (not energy instantly
consumed)
Monthly “Netting” Every month, SCE bills the customer for
“net” usage based on the difference between and
1 2
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Graphic Source: Pell Solar
Net Energy Metering (NEM) is an optional tariff for customer-generators who install a renewable generating facility to get a full retail rate credit for energy exported to the grid
Annual “Relevant Period” Within 12 months, customer-generators can use these “monthly net”
energy credits ($) to offset SCE charges for electricity usage. Therefore, customer-generators receive full retail credit for their
exported energy within the 12-month period.*
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1 2
How Current NEM Program Works
SCE Residential NEM Rate Structure
7¢
24¢ 17¢
0
5
10
15
20
25
30
¢/kW
h
Solar Subsidies
(Illustrative)
Avoided
Generation Subsidy Paid by
Other Ratepayers Equivalent
Solar Offset
Current NEM structure results in residential solar customers receiving
a subsidy funded by all other non-solar customers
SCE’s NEM Developments:
• On August 3rd, SCE filed a proposal with the CPUC that is more
reflective of solar systems’ total costs and benefits
Residential customers can consume their self-gen without any
charge
They purchase electricity from the utility at otherwise
applicable rates
They get paid for exported electricity at a fixed rate
representing utility’s avoided costs
They pay a monthly grid-access charge based on the size of
their system
SCE 2014 Net Energy Metering Statistics:
• 103,900 combined residential and non-residential projects – 880
MW installed (of 2,240 MW cap)
– 99.5% solar
– 100,300 residential – 500 MW
– 3,600 non-residential – 380 MW
• Approximately 1,270,000 kWh / year generated
Key Take-Aways
• SCE is committed to fully embracing and implementing California’s environmental sustainability, emissions reduction, and technology innovation vision, as well as meeting the changing customer expectations
• SCE will continue to transform distribution system planning and operations to meet current and future distributed energy resources goals
• SCE intends to partner with others to facilitate the deployment of low-carbon technologies and encourage customer value creation
• Utility grid modernization investments must keep pace with DER technology innovation
• SCE’s recently submitted DRP is an important step towards a fully integrated, low-carbon electricity system
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Thank you. To access SCE’s Distribution Resources Plan (DRP), SCE’s Distributed Energy Resources Interconnection Map (DERiM), and additional information, please visit the CPUC’s DRP website at: http://www.cpuc.ca.gov/PUC/energy/drp/
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