Nelly Wogberg <[email protected]>
Agenda item 5 for EC regarding DER
1 message
Rick DeGolia < > Sun, Nov 6, 2022 at 4:02 PM
Reply-To:
To: Jan Pepper >, Shawn Marshall , Nelly
Wogberg , Colson Julia Mates
Jeff Aalfs Rick Bonilla , Marty Medina
, Dave Pine Giselle Hale , Laura Parmer-Lohan , Pradeep Gupta , John Keener Cc: Michael Closson
Dear EC:
An agenda item for tomorrow is a CPUC program regarding DER in California. I apologize for the late email, but I think that the attached PDF is important. Attached is a document from the CPUC on this topic. Please read in particular pages 3 and 5 as the discussion will focus on the lack of inclusion of CCAs in this proposed significant program.
Nelly, please forward this to anyone else who may need it.
Thanks, Rick
Rick DeGolia
Atherton, CA 94027
650.793.2800 (m)
This email and any attachments thereto may contain private, confidential, and privileged material for the sole use of the intended recipient. Any review, copying, or distribution of this email (or any attachments thereto) by others is strictly prohibited. If you are not the intended recipient, please contact the sender immediately and permanently delete the original and any copies of this email and any attachments thereto. 2 attachments
10.19 CPUC community m....webloc
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10.19 CPUC community meeting slides.pdf
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California Public Utilities Commission 1
Informal Outreach Meetings
High Distributed Energy Resources (DER)
Grid Planning Proceeding
CPUC Energy Division
Proceeding No. R.21-06-017
California Public Utilities Commission
Meetings Hosts
• CPUC Energy Division Staff
• California Energy Commission Staff
• Gridworks Staff (consultants to CPUC)
• Meeting facilitation and meeting summary
• Verdant Staff (consultants to CPUC)
• Notes
2 California Public Utilities Commission
Goals for Today’s Meeting
1. Listen to stakeholders to gain an understanding and gather information about:
a. Community priorities with respect to energy (electric and gas); b. Community challenges and barriers to adopting clean energy technologies and distributed energy resources (DERs);
c. Community-specific, long-term visions and the role of electric utilities and DERs in achieving those visions;
d. How the CPUC and California Energy Commission can achieve meaningful community outreach and establish partnerships; and
e. How the utilities (PG&E, SCE, and SDG&E) can best include communities in electric distribution system planning.
2. Communicate to participants how insights from tribes, community-based and non-government organizations, and local governments will be used to:
a. Inform development of a draft scope of work for a statewide Community Engagement Needs Assessment to launch in 2023.
b. Gain insights about potential visions, objectives, and characteristics of a future electric grid for California to inform a Future Grid Study to be developed in 2023. 3 California Public Utilities Commission
Background: State Climate Goals
The State of California has established ambitious goals to address climate change. Among the goals, are to:
• Transition to renewable generation sources (100 percent clean electricity retail sales by 2045)
• Electrify vehicles (all new cars and light trucks sold in California to be zero-emission vehicles by 2035)
• Electrify heaters (all new furnaces and water heaters to be zero-emission by 2030)
4 California Public Utilities Commission
High DER Grid Planning Proceeding Overview (2021–2024)
In response to State climate goals, the California Public Utilities Commission (CPUC) opened the High Distributed Energy
Resources (DER) proceeding in 2021 to:
• Enable swift evolution of PG&E, SCE, and SDG&E grid
capabilities and operations to integrate solar, storage, electric vehicle/electric vehicle supply equipment and other DERs to meet the State’s 100 percent clean energy goals; • Improve distribution planning, including charging
infrastructure forecasting to support cost effective and widespread transportation electrification; and
• Optimize grid infrastructure investments by facilitating community input about planned developments, DER siting
plans, and resiliency needs.
5 California Public Utilities Commission
What are Distributed Energy Resources (DERs)
• Pursuant to State Assembly Bill 327 and Public Utilities Code Section 769(a), DERs include:
• A core objective of the CPUC’s High DER proceeding is to prepare the electric grid for a high distributed energy resource (DER) future by determining how to integrate millions of DERs within the distribution grid to maximize societal and ratepayer benefits from DERs while ensuring grid reliability and affordable rates.
6 Distributed Renewable
Generation Resources
such as solar
Demand
Response
Technologies
Energy
Storage Energy
Efficiency
Electric
Vehicles
Examples: Thermostats,
Internet-connected Water
Heaters
California Public Utilities Commission
Informal Outreach Meetings
7 • In October 2022, we’re setting up 10-15 informal meetings with:
• Community-based and non-government organizations;
• Tribes;
• Rural local governments; and
• Urban/suburban local governments.
• About 50 stakeholders from 35 organizations
• CPUC and California Energy Commission staff will participate in the meetings.
• A meeting summary will be prepared by the CPUC and
included with the draft scope of work for a statewide
Community Engagement Needs Assessment.
California Public Utilities Commission
Key Deliverables
8 • Community Engagement Needs Assessment
• What do communities want and need from electric distribution planning? • Develop scope of work for a consultant team to conduct statewide outreach to address this question.
• Hire a team and begin the assessment in 2023.
• Future Grid Study
• What are the options for electric distribution system operations for a future with high numbers of distributed energy resources? What are the trade-offs between different models of distribution grid operations?
• Complete the study in 2023 based on a series of technical workshops and stakeholder engagement to review and comment on the draft study.
California Public Utilities Commission
Next Steps and Further Participation
9 • Community Engagement Needs Assessment Workshop (Quarter 4, 2022) to present and receive comment on a draft scope of work for the assessment
• Draft scope of work issued prior to the workshop with outreach meetings summary appended
• At the workshop:
• Summary of outreach meeting outcomes with presentations by meeting participants or a panel
• Facilitate comments on the draft scope of work
• Technical workshops to begin Quarter 1, 2023 for development of the Future Grid Study (first workshop title, “Visions and Objectives for a Future Grid”)
California Public Utilities Commission
Proceeding Participation: Service List and Party Status 10 • The Service List receives all proceeding workshop and study issuance notices.
• Sign up for the High DER proceeding (R.21-06-017) service list using the form and Process Office email available at:
https://ia.cpuc.ca.gov/servicelists/sl_index.htm
• Choose to become a party to the High DER proceeding.
• For details, go to: https://www.cpuc.ca.gov/-/media/cpuc-website/divisions/news-and-outreach/documents/pao/party_081221.pdf California Public Utilities Commission
Distribution Planning Info
Slides Adapted from the Utility Distribution Planning Advisory Group primer workshop
11 California Public Utilities Commission
Electric Power System Overview
5 • The electric power system broadly consists of:
• Central-station bulk generation
• Transmission network (500 kV, 220 kV)*
• Transmission Substations
• Subtransmission network (SCE only, 115 kV, 66 kV)*
• Distribution Substations
• Distribution Circuits, aka “Feeders” (33 kV, 16 kV, 12 kV, 4 kV, 2.4 kV)*
*Typical voltages for SCE system are shown. Voltage levels may differ across IOUs.
Distribution
Customers
Transmission
Bulk Generation
Subtransmission
(SCE only)
Transmission and
Sub-transmission
Substations
Distribution
Substation
DPP
California Public Utilities Commission
California IOUs Have Diverse Topologies and
Service Areas Over 300,000 miles of distribution lines and over 1,500 substationsacross a variety of topologies:
• Urban and rural
• Mountain and valley
• Agricultural
• Coastal
13 California Public Utilities Commission
Distribution Planning vs. Distribution Operations
14 Distribution Operations Distribution Planning
Timeframe Real Time, 24/7 management of the
distribution grid
Mid to Long Term (1 to 10 years)
management of the distribution grid
System Configuration Possibly Abnormal or Emergency Normal Future Load Not used or useful Used to identify future grid needs in the Distribution Planning Process
Future Projects Not used or useful Identified through the Distribution Planning Process
Hidden Load Issue when it affects real time
loading
Annual issue when gathering
historic peak loadsfor planning
process
A Distribution Operations 101 presentation was given on August 23rd, 2022 and recorded.
The recording and other workshop material are available at the following URL:
https://gridworks.org/initiatives/california-future-grid-study/ California Public Utilities Commission
Distribution Planning Process Overview
8 Develop
Forecast
Determine
Capacity
Requirements
Evaluate
Alternatives
Public
Establish baseline assumptionsfor:
• Future load growth and loading profiles
• DER growth
• Distribution project deployment
Assess distribution grid capacity requirements to:
• Meet projected load and DER growth
• Maintain safety and reliability for end users
Evaluate project alternativesthat
cost-effectively address grid needs
and plan for the future
The Distribution Planning Process is an annual process that lasts 7-10 months and identifies projected distribution capacity deficiencies1 and determines mitigation plansto address those projected deficiencies. 1Distribution capacity deficiencies include capacity, voltage support,reliability (back-tie), and resiliency (microgrid).
California Public Utilities Commission
Load and DER Forecasts
Load Forecast
• System Level
• Utilize CEC’s Integrated Energy Policy Report (IEPR) (top down) forecast to establish system growth forecast.
• Substation Bank and Feeder Levels
• Utilize historical area loading (bottom up), economic indicators and temperature data to develop 1-in-10 year temperature adjusted load forecast at substation and circuit levels.
DER Forecast
• Future DER growth added to forecast
• DER hourly profiles are incorporated into the load forecast just as loads growth is incorporated.
Customer
Shapes
Total Feeder Shape
DER
Shapes
IEPR
Local Variables
Forecast
Public
California Public Utilities Commission
Determine Distribution System Capacity Needs
Timeline
• Process is performed on a yearly basis
Things to Consider
• Effects of planned utility projects on the needs of the system • Maintain operability to transfer customers during emergencies (Operational Flexibility) • Diversity of specific geographic load and customer mix • Effects on protection schemes due to projects
General Process
• Determine Thermal Capacity Needs
• Evaluate Voltage and Power Quality Needs
17 Public
California Public Utilities Commission
Substation and Bank Capacity Needs
• Compare existing capacity to forecast
• Evaluate substation equipment
• Determining:
• When? (i.e., 2024)
• How much? (i.e., 4 MW or 10%)
• Local Knowledge is needed to ensure accurate forecast such as:
• Historical regression
• Weather patterns
• Customer Mix
• Local construction, economics, and geography
• Identifying areas that have high potential for new known load additions (Downtown, Port, Etc.) 18 Public
California Public Utilities Commission
Distribution Circuit/Line Section
Capacity Needs • Compare existing capacity to forecast load • Evaluate circuit/line sections
• Determining:
• Overloaded circuits
• Emergency circuit transfer capability
• Granular information is needed to ensure accurate forecast such as:
• Local development projects
• Change in customer loads
• Projected area growth rates Distribution
Substation
New Load
Overload
19 Public
California Public Utilities Commission
Distribution Circuit Voltage Needs
• Compare reactive power needs to available supply, and review available voltage data
• Determining:
• Voltage levels on distribution circuits
• Reactive Power demands on circuit
• Voltage mainly affected by length of lines and load levels • Need to know length of lines and conductor sizes
• Reactive demands of loads
• Load diversity and variability
Distribution
Substation
New Wholesale DG
Voltage
Violation
20 Public
California Public Utilities Commission
Distribution Operations In Depth
& the Impact of DERs
Adapted from utility presentation July 26, 2022, Data Portals Workshop 21 Public
California Public Utilities Commission
Key Responsibilities of Distribution Operations
22 Public
• Responsible for the safe, efficient management
and 24/7 operations of the distribution grid
• Create and direct switching plans to
accommodate planned and emergency work
• Direct emergency switching to isolate fault
location and restore customers rapidly and safely
• Support large storm responses, major events and
incidents as required [earthquakes, solar
eclipses, major sporting events, atmospheric
rivers, wildfires]
• Monitor the distribution grid for real time overall power quality requirements • Coordinate with transmission control centers (where separate) • Coordinate between Planning and Operations regarding planned investments.
California Public Utilities Commission
Distribution Operations: Key Functions
23 Public
Function Location Description
System Operators Control Room Operates the grid to perform load transfersto minimize customer impacts for planned work and rapidly restore customers from unplanned outages.
Operations Engineers Control Room Assists operators to perform more complex maneuvers on the distribution grid Switching Program
Writers
Control Room Dedicated personnel to create switch programs for planned work Dispatchers Adjacent to Control
Room
Schedule various field resources to support operations and also direct various field resources for unplanned outages.
Troublemen Field Performs field activities to support operators, including but not limited to, executing switching requiring manual operations, patrolling circuits for damage, make safe activities for public safety hazards
Substation
Electricians/Operators
Field Performs field activities similar to troublemen but at substations Construction Crews Field Performs various overhead and underground construction jobs. Can also support troublemen on switching.
Scheduling
Coordination
Adjacent to Control
Room
Schedules and reschedules planned work into the system that requires system operators to manage workloads of operators and field
Outage Coordination Adjacent to Control
Room
Communication with customers on planned outages (scheduled and rescheduled) to ensure that they are well notified
Distribution
Line/Apparatus
Technicians
Field Performs and maintains programming / telecom of field devices.
California Public Utilities Commission
As DER penetration continues to increase and become more active in the marketplace, certain considerations are needed to ensure that the grid can be operated
1. Altered load profiles
2. Abnormal configurations created by switching creates un-studied constraints
3. Masked load impacts to switching operations
4. Local circuit constraints vs. system
High and Active DER Penetration
24 Public
California Public Utilities Commission
1. New Load Profiles and Grid Impacts from DER
Market Participation
Before Market Participation After Market Participation
California Public Utilities Commission
2. Outages and Abnormal Circuit Configurations
26 Public
• Radial distribution design is reconfigurable via
connections between feeders
• Many possible configurations adding
operational complexity
• Outages and abnormal circuit configurations
can create capacity constraints, which can
affect DERs’ ability to participate in wholesale
markets
California Public Utilities Commission
2. Outages and Abnormal Circuit Configurations
27 Public
California Public Utilities Commission
2. Outages and Abnormal Circuit Configurations
20 Public
California Public Utilities Commission
2. Outages and Abnormal Circuit Configurations
21 Public
California Public Utilities Commission
Current State
Operators only see real-time net loads at
existing SCADA measurement points and may
be unaware of the true load on each circuit
Future State
Increase DER Awareness for grid operations
will be provided by integration of all
measurement points and forecasting
capabilities with advanced analytics and a
power flow engine (i.e. Distribution State
Estimation)
Forecasted Gross Load
Circuit Capacity Limit
DER
Generation
Net Customer Load
Forecasted
Time of Day
Circuit Capacity Limit
Net Customer Load
Real-Time Only
Time of Day
At high levels of penetration awareness of DER impacts is necessary to ensure safe and efficient system reconfiguration during outage restoration, service planning, and maintenance 22 Public
3. Masked Load
California Public Utilities Commission
4. Local Circuit vs. CAISO Price Curve Alignment
MW
Pnode $
24-hour Period
MW
Pnode $
Feeder 1:
Market Prices are Correlated w/Feeder Load
Feeder 2:
Market Prices are NOT Correlated with Feeder Load
24-hour Period
Entire Year
1 1 1 1 1 1 1 1
.076 0 .79 .089 0 .75 0 .8 .09 0 .8 .093
1 0 .87 .09 .09 .076 .093 0 .98 .084
.087 0 .97 .087 0 .76 .082 .075 0 .93 .099
1 0 .82 .079 0 .89 .082 .083 0 .95 .082
.081 0 .95 .091 0 .91 .083 .084 0 .75 .083
.086 0 .92 .09 0 .75 .097 .083 0 .95 .097
.092 0 .93 .086 0 .86 .077 .083 0 .9 .095
.075 0 .75 .086 0 .89 .091 .097 0 .99 .085
.083 0 .77 .094 0 .84 .093 .096 0 .79 .085
.096 0 .96 .087 .09 .089 .084 0 .78 .097
.085 0 .77 .079 0 .86 .084 .077 0 .91 .084
.074 0 .56 .083 0 .6 .085 0 .74 .069
.062 0 .95 .05
0 .96
0 .89
.081 .057 0 .85 .077
.081 0 .71 .086 0 .68 .053 .068 0 .82 .074
.077 0 .79 .073 0 .58 .055 .097 0 .85 .065
.08 0 .8 .059 0 .91 .063 .084 0 .83 .082
.064 0 .57 .087 0 .66 .099 .069 0 .91 .063
.029 -0 .3
1 -.021 0 .41 .018 .019 0 .42 -.011
.028 0 .35 .028 0 .22 -.034 .01 0 .24 -.036
.036 -.006 -.034 -.04 .037 -.019 -.00
7 0 .06
.021 -0 .3 .04 .01 -.037 .049 -.00
5 -0 .05
.01 0 .19 -.043 -0 .2
1 -.049 0 .02 0 .34 -.012
-.071 -0 .7
5 -.092 -0 .6
6 -.061 -.057 -0 .9
3 -.064
-.091 -0 .5
6 -.088 -0 .85 -.074 -1 -0 .94 -.051
-.08 -0 .8
4 -.082 -0 .97 -.097 -.097 -0 .95 -.09 9
-1 -0 .9
8 -.084 -0 .96 -.096 -.082 -0 .81 -.088
-.099 -0 .7
5 -.088 -0 .78 -.076 -.086 -0 .95 -1
-1 -1 -1 -1 -1 -1 -1 -1
Spring Month of March Feeder
24-hour Period
(t0-t23h)
1 1 1 1 1 1 1 1
0 .97 0 .76 .094 .091 .096 0 .81 0 .76
0 .99 .09 .089 .082 .075 0 .78 0 .83
1 0 .86 .093 .085 .088 0 .94
0 .96
0 .91
0 .93
0 .83
0 .93 0 .94 .093 .08 .081 0 .91 0 .82 1
0 .78 0 .85 1 .085 .091 0 .88 0 .96 0 .79
0 .75 0 .75 .078 .088 .098 0 .78 0 .84 0 .92
0 .75 0 .86 .085 .085 .092 0 .81 0 .76 0 .87
0 .96 0 .97 .079 .092 .092 0 .99 0 .77 0 .98
0 .93 0 .99 .097 .077 .086 0 .92 0 .8 0 .96
0 .91 0 .76 .095 .099 .076 0 .96 0 .94 0 .93
0 .76 0 .93 .076 .087 .079 0 .85 0 .91 0 .86
0 .9 0 .53 .098 .071 .098 0 .68 0 .86 0 .57
0 .54 0 .58 .058 .089 0 .5 0 .95 0 .71 0 .84
0 .89 0 .77 .054 .066 0 .5 0 .56 0 .53 .05
0 .83 .07 .081 .086 .069 0 .57 0 .71 0 .66
0 .97 0 .58 .081 .069 .099 0 .52 0 .61 0 .53
0 .95 0 .75 .091 .05 .071 0 .73 0 .71
0 .76 0 .82 .072 .051 .069
0 .92
0 .94
0 .69 0 .65
-.00
9 0 .45 .035 0 .02 0 .1 -0 .12 0 .28 0 .17
.007 0 .41 .021 .039 -.037 -0 .3
5 0 .27 0 .49
-0 .4
5 -0 .11 -0 .05 -.032 .046 -0 .24 0 .15 0 .24
0 .36 -.009 .047 .023 -.032 0 .4 -0 .3
3 -0 .01
0 .16 -0 .1
1 0-.25 .-014 .047 -0 .46 0 .24 0 .16
-0 .1
2 .005 .016 -.01 -.027 0 .13 -.005 0 .26
.004 0 .23 -0 .02 -.037 .033 -.00
5 0 .28 -0 .23
-0 .7
7 -0 .86 -.09 -.079 -.089 -0 .95 -0 .85 -0 .86
-0 .8
4 -0 .86 0-.78 .-094 .-089 -0 .99 -0 .76 -0 .82
-1 -1 -1 -1 -1 -1 -1 -1
1 1 1 1 1 1 1 1
23 Public
.098 0 .92 .099 0 .94 .083 1 1 .085
.078 0 .82 .08 0 .96 .087 .087 0 .98 .094
.081 0 .9 .091 0 .88 .084 .085 0 .84 .094
.079 0 .97 .087 0 .87 .093 .096 0 .9 8.081
.075 0 .83 .09 0 .91 .083 .09 0 .76 .081
.086 0 .81 .083 0 .91 .098 .082 0 .88 .086
.082 0 .93 .078 0 .94 1 .089 0 .93 1
.089 0 .75 .077 0 .75 .087 .078 0 .81 .088
.097 0 .94 .093 0 .92 .094 .089 0 .85 .086
.097 0 .8 .097 0 .98 .083 .08 0 .9 .095
.078 0 .8 .083 0 .81 .075 .086 0 .97 .08
.074 0 .88 .091 0 .87 .073 .082 0 .68 .086
.095 1 .074 0 .89 .089 .074 0 .87 .065
.084 0 .71 .096 0 .58 0 .6 .098 0 .55 .078
.08 0 .95 .079 1 .077 .088 0 .61 .074
.068 0 .85 .065 .07 .085 .097 0 .97 .061
.056 0 .63 .071 0 .62 .058 .087 0 .88 .09
.062 0 .71 .096 0 .89 .053 .089 0 .71 .096
.073 0 .56 .089 0 .51 .098 .068 0 .53 .071
.099 0 .98 .087 0 .52 .082 .084 0 .67 .068
.096 0 .55 .075 0 .97 .076 .059 0 .81 .052
.054 0 .68 .087 0 .68 .052 .076 0 .9 .081
-.011 0 .43 .032 -0 .1
7 0 .5 -.022 0 .18 .034
.013 -0 .1 0 .06 -0 .4
2 -.017 .033 0 .43 -.011
.011 0 .2 0 .07 0 .34 .039 .035 -0 .2
9 -.041
-.037 0 .31 .025 -0 .3
6 -.023 .013 -0 .2
7 -0 .01
-0 .08 -0 .3
6 -0 .06 .005 .039 .049 0 .22 -.019
-.091 -0 .91 -.088 -0 .87 -.082 -.089 -0 .96 -.097
Feeder
24-hour Period
(t0-t23h)
Feeder
24-hour Period
(t0-t23h)
Green:
Positive
Strong
Correlation
Red:
Negative
California Public Utilities Commission
Additional Slides
32 California Public Utilities Commission 33
We Anticipate a High-Penetration Distributed
Energy Resource (DER) Future
“This OIR neither seeks to set policy on the overall number of DERs nor does it seek to increase or decrease the desired level of DERs.
This OIR focuses on preparing the grid to accommodate what is expected to be a high DER future and capture as much value as possible from DERs as well as mitigate any unintended negative impacts.”
– High DER OIR at p. 10
“This OIR anticipates a high-penetration DER future and seeks to determine how to optimize the integration of millions of DERs within the distribution grid while ensuring affordable rates.” – High DER OIR at p. 9
California Public Utilities Commission
Three High DER Proceeding Tracks
34 1
Distribution Planning Process
and Data Improvements
Ø Phase 1: Near-Term Actions
Ø Phase 2: Distribution Planning
Process Improvements
Ø Topics:
• IOU Distribution Planning
Processes
• Electrification Impacts and
Potential Mitigation
• Data Portals
• Community Engagement
Needs Assessment for
Distribution Planning
2 Distribution System Operator
(DSO) Roles and
Responsibilities
3 Smart Inverter
Operationalization and Grid
Modernization Planning
Ø Long-term grid vision(s) and
associated policy issues
Ø Investigation of grid
operations models
Ø Future Grid Study
development and public
outreach
Ø Future actions identified that
could lead to a successor
proceeding
Ø Phase 1: Smart
Inverter Operationalization
Ø Phase 2:
Grid Modernization
Planning and Cost
Recovery
Ø Topics:
• Business Use Cases
for Smart Inverters
• DER Dispatchability
• Smart Grid
Investment Planning
California Public Utilities Commission
Work Plan
35 California Public Utilities Commission
Work Plan Timeline
(2021-2022)
36 Legend • Bold are staff proposals
and Decisions
• Proceeding Track 1 • Distribution Investment
Deferral Framework (DIDF)
• Distribution Planning
Process (DPP)
• Electrification Impact
Study (EIS)
• Proceeding Track 2 • Proceeding Track 3 • Smart Inverter Operationalization (SIO)
• Working Group (WG) • General Rate Case (GRC)
California Public Utilities Commission 37
Work Plan Timeline (2021-2025)
California Public Utilities Commission
Scoping Questions & Key
Deliverables
38 California Public Utilities Commission
Track 1 Scoping Questions About Distribution
Planning and Community Engagement
39 Track 1, Phase 1
#5. What initial analysis is needed for the Commission to determine in Track 1, Phase 2, of this proceeding how best to improve local engagement in utility distribution planning?
• See also, Scoping Ruling at p. 13, “Energy Division will conduct a workshop on the scope and funding of a potential community engagement needs assessment during the third quarter of 2022 to inform Track 1, Phase 2 of this proceeding.” Track 1, Phase 2
#3. Leveraging the analysis identified in Track 1, Phase 1, are there ways in which utility distribution planning representatives could better engage with local and tribal governments, Environmental and Social Justice communities, and local developers to ensure new planned loads and developments are factored into Utility Distribution Planning Processes and local concerns regarding distribution planning are adequately addressed? Note: The full list of scoping questions is provided in the proceeding’s Scoping Ruling.
California Public Utilities Commission
Track 1 Community Engagement Needs Assessment
40 • Among the many Track 1 goals are to improve utility distribution planning to be more responsive to the needs and plans of communities.
• An external consultant is anticipated to create and implement a Community Engagement Needs Assessment to determine what communities want and need from distribution planning.
• The scope and cost of the needs assessment would be approved by the CPUC via a Decision.
• The scope of work for the needs assessment will be developed in a Quarter 4, 2022 stakeholder workshop and released via a staff proposal following the workshop.
California Public Utilities Commission
Track 2 Scoping Questions and Future Grid Study
41 #1. How do alternative DSO models compare in their ability to plan and operate a high DER grid, unlock economic
opportunities for DERs to provide grid services, limit market power, reduce ratepayer costs, increase equity, support grid resiliency, and meet State policy objectives?
#2. Should the Utilities be incentivized to cost-effectively prepare for widespread DER deployments? If so, how?
Ø The Future Grid Study is the primary deliverable planned for Track 2. It is designed to address these two scoping
questions. For further details, see:
https://gridworks.org/initiatives/california-future-grid-study California Public Utilities Commission
Track 2 Future Grid Study
42 • The study would explore, assess, and develop a detailed strategy for options to evolve California’s electric grid to the grid of the future—one that enables the full integration of DERs cost effectively, safely, reliably, and in line with State policy.
• Stakeholders would be included in the development of California’s vision for the future grid, its design principles, the required functionality, and each step that must be taken to meet these objectives. • Various Distribution System Operator models would be explored and options for piloting feasible models would be identified. • The models evaluated might be prioritized according to likelihood of future implementation or highlighted for additional study.
• We expect issues appropriate for a successor proceeding and potential legislative action to be identified for consideration during the Study development and review processes.
California Public Utilities Commission
Technical Workshop Series for Study Development
43 • Workshop 1 (Q1 2023): Visions and Objectives for a Future Grid • Workshop 2 (Q1/Q2 2023): Operations Needed for the Future Grid • Workshop 3 (Q2 2023): Gap Assessment, Collect Additional Gap Information
• Workshop 4 (Q2/Q3 2023): Present and Socialize Distribution System Operator Model Proposals
• Workshop 5 (Q3 2023): Identify Barriers, Actions, Trade-Offs California Public Utilities Commission
Robust and Meaningful Comments on the Draft Future
Grid Study
44 • To ensure robust comments are received on the Draft Future Grid Study, including from stakeholders that have not traditionally participated in CPUC proceedings on energy issues, Staff expect that outreach already scoped for Track 1 will be coordinated with Track 2.
• This would be accomplished by ensuring that the scope of work to be developed for the Track 1 Community Engagement Needs Assessment includes widespread education and outreach
support specific to the Draft Future Grid Study.
• Support for repeating the educate-listen-focus principles during widespread outreach in the State and among diverse communities would be included.
• Scope of work approval, including funding for consultant support, would be determined in a Track 1 Proposed Decision.
California Public Utilities Commission
Other Deliverables by High DER Track
45 • T1: Research Plan for Electrification Impacts Study • T2: White Paper for Future Grid Study
• T1: Community Engagement Needs Assessment Scope of Work • T1: Distribution Investment Deferral Framework Guidelines • T1: Electrification Impacts Study (Parts 1, 2, and 3) • T3: Smart Inverter Operationalization Working Group Report • T3: Smart Inverter Operationalization Staff Proposal
• T2: Future Grid Study
• T1: Community Engagement Needs Assessment Report
• T3: Grid Modernization Plan Improvement and GRC
Alignment Staff Proposal
• T1: Data Portal Improvement Technical Report
• T1: Distribution Planning Process Guidelines Staff Proposal