Agenda packet, first session — Glendale City Council, November 19, 2024 (part 1 of 2)

A G E N D A

GLENDALE CITY COUNCIL

COUNCIL CHAMBERS
613 E. Broadway, 2nd Floor
Glendale, CA 91206
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NOVEMBER 19, 2024

ROLL CALL

1. CLOSED SESSION
– 1:00 PM
a.

Conference with Legal Counsel - Anticipated Litigation: Initiation of litigation pursuant to paragraph (4) of subdivision (d) of Government Code Section 54956.9:

One potential case

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Public Employment – Attorneys
c.

Conference with Real Property Negotiators: City-designated negotiators: Roubik Golanian, John Takhtalian, Onnig Bulanikian, Michael J. Garcia, Gillian van Muyden, Michele Flynn, Bradley Calvert and Mark Berry. Property Location: 440 and 444 W.

Cypress St., 1275, 1291-1295, and 1295A Los Angeles St., and 448 Fernando Ct.

Negotiating Parties: CPD Los Angeles LLC. Instructions to the negotiator(s) will concern the price and terms of payment for the acquisition of property d.

Conference with Legal Counsel – Existing Litigation: Panosian v. City of Glendale, L.A.S.C. Case No. 23GDCV00932

2. REGULAR BUSINESS AGENDA
– 6:00 PM
Roll Call
a.

Flag Salute: Mayor Elen Asatryan
b.

Invocation: Dr. Suzie Abajian, City Clerk
c.

Report of the City Clerk, re: Posting of Agenda. The Agenda for the November 19, 2024 Regular Meeting of the Glendale City Council was Posted on November 14, 2024, on the Bulletin Board Outside City Hall.

3. PRESENTATIONS AND APPOINTMENTS
a.

Agenda Preview for the Meetings of Tuesday, November 26, 2024 b.

Legislative Update by Kyra Ross
c.

Proclamation Designating Saturday, November 30th, as “Small Business Saturday” d.

Commendation for Palace Cleaners & Laundry for their 101 Years in Business

City Clerk, re: Minutes of the Special City Council and Regular City Council Meetings of November 12, 2024

5. CITY COUNCIL/STAFF COMMENTS

6. COMMUNITY EVENT ANNOUNCEMENTS (3-Minutes; 5-Speaker Limit) Per Mayor Policy, This Item Also Permits Speakers Wishing to Speak Under General Oral Communications, Subject to the Three Minute Time Limit. Discussion is Limited to Matters Not on the Agenda.

7. ADOPTION OF ORDINANCES

8. ACTION ITEMS
a.

Glendale Water and Power, re: Glendale Water and Power (GWP) Power Source Disclosure Report and Power Content Label for Calendar Year 2023

1. Motion to Note and File the GWP Power Disclosure Report and Power Content Label for Calendar Year 2023
b.

Glendale Water and Power, re:

Plan to Increase Glendale Water and Power (GWP)

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Customer Solar Adoption and Develop Additional Distributed Energy Resources

1. Motion accepting the findings of the Energy and Environmental Economics, Inc. (E3) study on GWP’s Plan to Increase Solar Adoption and Develop Additional Distributed Energy Resources, as outlined in the Final Report: Plan to Increase Solar Adoption and Develop Additional Distributed Resources

2. Resolution amending Resolution No. 22-125 to revise the target of achieving a minimum total peak dispatchable and peak-load-reducing capacity of 100 MW by December 31, 2027 to a target of achieving 60 MW of solar generating capacity by 2030, and approving the development of programs to enhance energy efficiency and reduce peak demand

3. Motion amending the City’s existing Professional Services Agreement (PSA), Contract No. 8002375, with E3, to increase the amount by $52,330 for additional completed work and to authorize the corresponding encumbrance
c.

Management Services, re:

Appointment of City of Glendale Member to the Board of
Directors for the Metropolitan Water District (MWD) of Southern California

1. Motion appointing an individual to serve on the Board of Directors for the Metropolitan Water District of Southern California

9. HEARINGS
a.

Community Development, re: Ordinances Amending Title 30 of the Glendale Municipal Code, 1995, (Case No. PZC-0010-2024) and the Downtown Specific Plan (Case No. PGPA-003908-2024) Relating Generally to Standards for Accessory Dwelling Units (ADUs) and Junior Accessory Dwelling Units (JADUs) (Continued from November 12, 2024, Council Meeting)

1. Introduction of Ordinance Amending Title 30 Relating Generally to Standards for ADUs and JADUs

2. Introduction of Ordinance Amending the Downtown Specific Plan Relating Generally to Standards for ADUs and JADUs

3. Resolution Making Findings That Certain Portions of Ordinance No. 5997 Complies with California Government Code Sections 66314, et seq. and 66333, et seq., Despite the Findings of the California Department of Housing and Community Development, Which Findings Are Required Pursuant to California Government Code Section 66326 Prior to Re-adopting Those Portions of Ordinance No. 5997 Without Changes b.

Public Works, re:

Appeal of Transportation and Parking Commission Decision Regarding Installation of All-way Stop Controls at the Adams Street and Scofield Drive Intersection

1. Motion reversing the decision of the Transportation and Parking Commission, and approving the installation of all-way stop controls; or, in the alternative

2. Motion affirming the decision of the Transportation and Parking Commission, and denying the installation of all-way stop controls; or, in the alternative

3. Motion referring the matter back to the Transportation and Parking Commission, with directions, for further consideration; or, in the alternative

10. REPORTS - INFORMATION

11. WRITTEN COMMUNICATIONS

12. DISCUSSION OF COUNCILMEMBER FUTURE AGENDA REQUESTS
a.

Councilmember Brotman’s Request to Discuss updating development standards to

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address illumination levels on private property (Carried over from October 8, November 5, and November 12, 2024, Council Meeting)
b.

Councilmember Brotman’s Request to Consider different approaches for drive- through regulations, including updated development standards (Carried over from October 8, November 5, and November 12, 2024, Council Meeting) c.

Mayor Asatryan’s Request for a Report on Funding and/or Policies for Further Rent Reductions in the City/Authority’s Affordable Housing Projects for Tenants on SSI (Carried over from November 12, 2024, Council Meeting)

13. ORAL COMMUNICATIONS
Discussion is Limited to Items NOT a Part of this Agenda. Each Speaker is Allowed 5 minutes.

Council May Question or Respond to The Speaker But There Will be no Debate or Decision.

The City Manager May Refer the Matter to the Appropriate Department for Investigation and Report.

14. NEW BUSINESS

15. ADJOURNMENT

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1 M I N U T E S
SPECIAL MEETING: GLENDALE CITY COUNCIL

COUNCIL CHAMBERS
613 E. Broadway, 2nd Floor
Glendale, CA 91206
NOVEMBER 12, 2024
The Special Public Meeting of the Glendale City Council convened in the City Hall Council Chambers, in said City, at 3:04 p.m., on the above date, pursuant to a call for such meeting signed by the City Clerk of the City Council, and on file with the City Clerk, a copy of which is as follows:

November 7, 2024
Date
A SPECIAL PUBLIC MEETING of the City Council is hereby called to meet at 3:00 PM on Tuesday, November 12, 2024, in the Council Chamber, 613 E. Broadway, 2nd Floor, Glendale, CA 91206 to consider the following item(s) of business, to wit;

1. Community Development, re: Public Hearing for Stage I Preliminary Design Review Case No. PDR-002693-2023 to construct a New 105-unit, 8-story Multi-Family Building with 215 Parking Spaces and Public Open Space Area on a 36,170 square- foot site, located at 820 North Central Avenue, 208 Arden Avenue, and 212 Arden Avenue, in the DSP zone
a. Motion to Approve Stage I Preliminary Design Review
Written Notice of said meeting was given, which Notice consisted of a copy of the foregoing Call, and was served on each Member of the Council not joining in the Call, and upon the in said City not less than 24 hours before the time fixed in said Call for said meeting, as follows:

Upon Dan Brotman at 5:00 p.m. October 9, 2024 Glendale, CA Upon Vartan Gharpetian at 5:00 p.m. October 9, 2024 Glendale, CA Upon Ardy Kassakhian at 5:00 p.m. October 9, 2024 Glendale, CA Upon Ara Najarian at 5:00 p.m. October 9, 2024 Glendale, CA Upon Elen Asatryan at 5:00 p.m. October 9, 2024 Glendale, CA Mayor Asatryan called the meeting to order at 3:04 p.m.

ROLL CALL
- Absent: Brotman, Kassakhian
- Report of the City Clerk of the City Council, re: Posting of Agenda. The Agenda for the Tuesday, November 12, 2024, Special Public Meeting of the City Council was posted on November 7, 2024, on the Bulletin Board Outside City Hall.

2 Presenting:

Aileen Babakhani, Sr. Planner
Rodney Khan, Developer
Ron Mandalian, Architect
Staff Comment:

Bradley Calvert, Director of Community Development
a. Motion to Approve Stage I Preliminary Design Review
Moved: Gharpetian Seconded: Najarian
Vote as Follows
ADJOURNMENT – 3:38 p.m.

Moved: Najarian Seconded: Gharpetian
Mayor of the City of Glendale
City Clerk of the City of Glendale
Ayes:

Noes:

Absent:

Abstain:

Gharpetian, Najarian, Asatryan
None
Brotman, Kassakhian
None
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1 M I N U T E S

GLENDALE CITY COUNCIL

COUNCIL CHAMBERS
613 E. Broadway, 2nd Floor Glendale, CA 91206
NOVEMBER 12, 2024

ROLL CALL

1. CLOSED SESSION
a. Public Employment – Attorneys

2. REGULAR BUSINESS AGENDA – 6:03 PM
Roll Call – Absent: Brotman, Kassakhian
a. Flag Salute: Mayor Elen Asatryan
b. Invocation: Dr. Suzie Abajian, City Clerk
c. Report of the City Clerk, re: Posting of Agenda. The Agenda for the November 12, 2024, Regular Meeting of the Glendale City Council was Posted on November 7, 2024, on the Bulletin Board Outside City Hall.

3. PRESENTATIONS AND APPOINTMENTS
a. Agenda Preview for the Meetings of Tuesday, November 19, 2024 Asst. City Manager John Takhtalian provided the preview.

4. CONSENT ITEMS (Including Minutes)
The following are Routine and May be Acted Upon by One Motion. Any Member of Council or the Audience Requesting Separate Consideration May do so by Making Such Request Before Motion is Proposed.
a. City Clerk, re: Minutes of the Joint City Council and Housing Authority and Regular City Council Meetings of November 5, 2024
Moved: Najarian Seconded: Gharpetian
Vote as Follows
b. Public Works, re: Public Works Department Building Maintenance and Repair Services at Various City Facilities

1. Resolution 24-180 Adopting Specification No. 3989, for Electrical Systems Services at Various City Facilities Project, and Directing the City Clerk to Advertise for Bids Moved: Najarian Seconded: Gharpetian
Vote as Follows
Ayes:

Noes:

Absent:

Abstain:

Gharpetian, Najarian, Asatryan
None
Brotman, Kassakhian
None
4A
Ayes:

Noes:

Absent:

Abstain:

Gharpetian, Najarian, Asatryan
None
Brotman, Kassakhian
None
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2 2. Resolution 24-181 Adopting Specification No. 3990, for Flooring Services at Various City Facilities Project, and Directing the City Clerk to Advertise for Bids Moved: Najarian Seconded: Gharpetian
Vote as Follows

3. Motion executing a change order to contract 8001567 with Omega Construction Co.

Inc. for Citywide General Building Repairs, increasing the contract amount by $300,000 and extending the contract duration by two years, and authorizing the City Manager or his designee to execute the contract change order Moved: Najarian Seconded: Gharpetian
Vote as Follows

4. Motion executing a change order to Contract 8001569 with Prime Painting Contractors Inc. for Citywide Maintenance and Repair of Paining Systems, increasing the contract amount by $240,000 and extending the contract duration by two years, and authorizing the City Manager or his designee to execute the contract change order
Moved: Najarian Seconded: Gharpetian
Vote as Follows

5. Motion executing a change order to Contract 8001570 with H.L. Moe Co. Inc. for Citywide Maintenance and Repairs of Plumbing Systems, increasing the contract amount by $267,000 and extending the contract duration by two years, and authorizing the City Manager or his designee to execute the contract change order Moved: Najarian Seconded: Gharpetian
Vote as Follows
Ayes:

Noes:

Absent:

Abstain:

Gharpetian, Najarian, Asatryan
None
Brotman, Kassakhian
None
Ayes:

Noes:

Absent:

Abstain:

Gharpetian, Najarian, Asatryan
None
Brotman, Kassakhian
None
Ayes:

Noes:

Absent:

Abstain:

Gharpetian, Najarian, Asatryan
None
Brotman, Kassakhian
None
Ayes:

Noes:

Absent:

Abstain:

Gharpetian, Najarian, Asatryan
None
Brotman, Kassakhian
None
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3 6. Motion executing a change order to Contract 8001571 with AME Builders Inc. for Citywide Maintenance and Repair of Roofing Systems, increasing the contract amount by $267,000 and extending the contract duration by two years, and authorizing the City Manager or his designee to execute the contract change order Moved: Najarian Seconded: Gharpetian
Vote as Follows

5. CITY COUNCIL/STAFF COMMENTS
Councilmembers wished everyone a belated Happy Veterans Day and thanked our veterans for their sacrifices and services to our country. Gharpetian echoed Councilmember Kassakhian’s comment from last meeting that the City of Glendale should host an event next year to celebrate our veterans. Gharpetian attended Glendale Police Foundation’s Annual k-9 Comedy Night, YMCA Evening of Excellence Gala, and the Glendale Association of Realtors Annual CanTree Fundraising Event.

Mayor Asatryan announced that the Comprehensive Community Health Centers opened an urgent care facility in Glendale which is now open from 6pm-9pm. She congratulated the Economic Development Department that made the City of Glendale recognized as one of the five “Business-Friendly Cities” in Los Angeles County. Asatryan met with the Associated Students of Glendale Community College last week to discuss advocating for funding for immigrant students at the state level. She also had a conversation with previous leadership of the Glendale Community College on how the city can engage, specifically the Associated Student Body, in getting feedback as the city is developing the transportation plan which would be different than the administration of Glendale Community College.

City Attorney Mike Garcia stated that the 60-day cut-off for the nomination panels to make nominations for boards and commissions expires on November 16th. Therefore, under Resolution No. 24-156, that deadline is being extended by 30 days. The new deadline for the panels to make nominations will be December 16, 2024.

Allen Dish
Allan Durham

7. ADOPTION OF ORDINANCES

8. ACTION ITEMS
Ayes:

Noes:

Absent:

Abstain:

Gharpetian, Najarian, Asatryan
None
Brotman, Kassakhian
None
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4 9. HEARINGS
a. Community Development, re: 1504 Bel Aire Drive: Consideration of Glendale Register Nomination and Request for a Mills Act Historic Property Contract Hearing opened at 6:17 p.m. and closed at 6:31 p.m.

Presenting:

Ani Mnatsakanyan, Planner
Public Comments:

Tim Scully, owner
Shane Lee
Allan Durham
Fernando Roldan

1. Resolution 24-182 to designate the residential property at 1504 Bel Aire Drive as a historic resource in the Glendale Register of Historic Resources and authorize the City Manager to enter into a Mills Act Historical Property Contract with the property owner
Moved: Gharpetian Seconded: Najarian
Vote as Follows

2. Motion to deny the request of the property owner to designate the residential property at 1504 Bel Aire Drive as a historic resource in the Glendale Register of Historic Resources
b. Community Development, re: 3235 Cornwall Drive: Consideration of Glendale Register Nomination and Request for a Mills Act Historic Property Contract Hearing opened at 6:32 p.m. and closed at 6:51 p.m.

Presenting:

Ani Mnatsakanyan, Planner
Staff Comments:

Bradley Calvert, Director of Community Development
Jay Platt, Principal Planner
Public Comment:

Shane Lee

1. Resolution 24-183 to designate the residential property at 3235 Cornwall Drive as a historic resource in the Glendale Register of Historic Resources, as the Porter House, and authorize the City Manager to enter into a Mills Act Historical Property Contract with the property owner
Ayes:

Noes:

Absent:

Abstain:

Gharpetian, Najarian, Asatryan
None
Brotman, Kassakhian
None
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5 Moved: Gharpetian Seconded: Najarian
Vote as Follows

2. Motion to deny the request of the property owner to designate the residential property at 3235 Cornwall Drive as a historic resource in the Glendale Register of Historic Resources
c. Community Development, re: Property Owner Request for a Mills Act Historical Property Contract for 2535 E. Chevy Chase Drive (Derby House, Glendale Register No. 22)
Hearing opened at 6:57 p.m. and closed at 7:09 p.m.

Presenting:

Jay Platt, Principal Planner
Public Comments:

Shane Lee
Allan Durham

1. Resolution 24-184 authorizing the City Manager to enter into a Mills Act Historical Property Contract with the owner of 2535 E. Chevy Chase Drive Moved: Gharpetian Seconded: Najarian
Vote as Follows
d. Community Development, re: Ordinances Amending Title 30 of the Glendale Municipal Code, 1995, (Case No. PZC-0010-2024) and the Downtown Specific Plan (Case No. PGPA-003908-2024) Relating Generally to Standards for Accessory Dwelling Units (ADUs) and Junior Accessory Dwelling Units (JADUs) (To Be Continued Without Further Notice to the November 19, 2024, Council Meeting) Motion to continue without further notice to November 19, 2024, Council Meeting Moved: Gharpetian Seconded: Najarian
Vote as Follows
Ayes:

Noes:

Absent:

Abstain:

Gharpetian, Najarian, Asatryan
None
Brotman, Kassakhian
None
Ayes:

Noes:

Absent:

Abstain:

Gharpetian, Najarian, Asatryan
None
Brotman, Kassakhian
None
Ayes:

Noes:

Absent:

Abstain:

Gharpetian, Najarian, Asatryan
None
Brotman, Kassakhian
None
11 of 559

6 10. REPORTS – INFORMATION

11. WRITTEN COMMUNICATIONS

12. DISCUSSION OF COUNCILMEMBER FUTURE AGENDA REQUESTS
Items 12a, 12b, and 12c moved to November 19, 2024, Council Meeting. a. Councilmember Brotman’s Request to Discuss updating development standards to address illumination levels on private property (Carried over from October 8 and November 5, 2024, Council Meeting)
b. Councilmember Brotman’s Request to Consider different approaches for drive- through regulations, including updated development standards (Carried over from October 8 and November 5, 2024, Council Meeting)
c. Mayor Asatryan’s Request for a Report on Funding and/or Policies for Further Rent Reductions in the City/Authority’s Affordable Housing Projects for Tenants on SSI

13. ORAL COMMUNICATIONS
Discussion is Limited to Items NOT a Part of this Agenda. Each Speaker is Allowed 5 minutes. Council May Question or Respond to The Speaker But There Will be no Debate or Decision. The City Manager May Refer the Matter to the Appropriate Department for Investigation and Report.

Randy Stevenson
Allan Durham
Nara
Fernando

14. NEW BUSINESS

15. ADJOURNMENT – 7:23 p.m.

Moved: Najarian Seconded: Gharpetian
Mayor of the City of Glendale
City Clerk of the City of Glendale
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CITY OF GLENDALE, CALIFORNIA

REPORT TO THE CITY COUNCIL

AGENDA ITEM
Report: Glendale Water and Power (GWP) Power Source Disclosure Report and Power Content Label for Calendar Year 2023.

1. Motion to Note and File the GWP Power Disclosure Report and Power Content Label for Calendar Year 2023.

COUNCIL ACTION
Item Type: Action Item
Approved for November 19, 2024 calendar

EXECUTIVE SUMMARY
Each year, the City Council reviews and files the Power Source Disclosure (PSD) Report and the accompanying Power Content Label (PCL), which are generated as part of the California Energy Commission’s (CEC) Power Source Disclosure program. The PCL offers a comprehensive breakdown of GWP’s power supply sources serving its customers and how these compare to California’s "grid average" power mix. The data is inventoried and independently verified, ensuring transparency in GWP’s power supply portfolio. The PCL is published each fall, covering the previous calendar year, and is presented to the City Council.

RECOMMENDATION
Note and file this GWP PSD Report and associated PCL for Calendar Year 2023.

ANALYSIS
The annual PSD Report, which is attached to this Report as Exhibit A, and associated PCL, which is attached to this Report as Exhibit B, is prepared using the same Open Access Technology International (OATI) electronic tagging information (e-tags), Western Renewable Energy Generation Information System (WREGIS) renewable energy credits (RECs), metered generation, and load data that is obtained by GWP staff for financial settlements. The data collected is also used for Renewable Portfolio Standard (RPS) and Greenhouse Gas (GHG) tracking and reporting purposes.

On June 21, 2024, GWP submitted the annual PSD report for calendar year 2023 to the CEC. A revised PSD report (Exhibit A) was re-submitted to the CEC on September 11, 2024, after all the MWh were verified.
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28a
5 5
6 6
The 2023 annual PSD and PCL reports have been verified by an independent auditor for accuracy and completeness and it was concluded that all procedures were performed in accordance with CEC regulations.

Glendale’s 2023 Power Content Label
Percentages are provided annually by the CEC based on the electricity sold to California consumers during the identified year. The City of Glendale 2023 PCL was posted on the GWP website on October 1, 2024.
https://www.glendaleca.gov/government/departments/glendale-water-and-power/about- us/power-content-label.

The PCL will also be mailed to each utility customer as a bill insert from October 23, 2024 through December 23, 2024.

In 2023, GWP’s renewable percentage was 35.3%, which maintains our position from 2022 (35.2%). GWP remains impacted by a delay in commercial operation date (COD) and an underproduction of various renewable energy resources such as geothermal plants Star Peak and Whitegrass.
2023 PO WER CO NT ENT LABEL
G lendale Water and Power
www.G lendaleCA.gov/PowerContentLabel
Gre e nhouse Ga s Em issions
Inte nsity (lbs CO 2e /M W h)
Ene rgy Re source s
Glendale
W ater and
Pow er
2023 CA
Pow er Mix
Eligible Re ne w a ble 1 35.3% 36.9%
Biom as s & Biow as te 0.0% 2.1%
515 373 Geotherm al 8.8% 4.8%
Eligible H ydroelectric 1.6% 1.8%
Solar 16.8% 17.0%
Wind 8.1% 11.2%
Coa l 1.6% 1.8%
La rge Hydroe le ctric 8.8% 11.7%
Na tura l Ga s 32.5% 36.6%
Nucle a r 11.0% 9.3%
Othe r 0.0% 0.1%
Unspe cifie d Pow e r2 10.9% 3.7%
TOTAL 100.0% 100.0%
Percentage of Retail Sales Covered by
Retired Unbundled RECs
3 :
< 1 %
1 The eligible renew able percentage above does not reflect R PS com pliance, w hich is determ ined us ing a different m ethodology.
2 U ns pecified pow er is electricity that has been purchas ed through open m arket trans actions and is not traceable to a s pecific generation s ource. 3 R enew able energy credits (R EC s ) are tracking ins trum ents is s ued for renew able generation. U nbundled renew able energy credits (R EC s ) repres ent renew able generation that w as not delivered to s erve retail s ales . U nbundled R EC s are not reflected in the pow er m ix or GH G em is s ions intens ities above.

For specific inform ation about
this electricity portfolio, contact:

Gle nda le W a te r a nd Pow e r
855-550-4497
For general inform ation about
the Power Content Label, visit:
https://www.energy.ca.gov/program s-and-
topics/program s/power-source-disclosure-program
Glendale Water and
P o wer
2023 C A Utility
A v erage
0 2 0 0
4 0 0
6 0 0
8 0 0
1 0 00
Glendale
Water and
Power
2023 CA Utility
Average
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38a
5 5
6 6
In 2023, GWP observed an increase in the use of unspecified power sources due to the ongoing demolition and new construction of the Grayson Power Plant. As the plant undergoes construction, the temporary reduction in local generation capacity has demanded greater reliance on external unspecified power to meet the community’s energy needs. In contrast, during 2022, the Grayson Power Plant was still operational, providing consistent energy output that significantly reduced the need for unspecified power. The increase of unspecified power will continue until the completion of the new Scholl Canyon Biogas Project and new Grayson Power Plant facility, which are currently scheduled for summer of 2025 and summer of 2026, respectively.

A total of 798 unbundled RECs generated from GWP’s incentivized photovoltaic (PV) rooftop solar installations were retired for Renewable Portfolio Standard compliance during this reporting period, representing 0.1% of GWP’s retail sales.

The City of Glendale has continued to make significant strides in achieving clean energy goals, reaching an impressive 55.1% clean energy generation in 2023. This achievement is largely due to our Renewable Portfolio Standards (RPS) sources, as well as clean energy from large hydroelectric and nuclear power facilities. By maintaining this commitment to clean power, the City of Glendale continues to exceed California’s clean energy mandates, consistently providing its customers with clean energy.

STAKEHOLDERS/OUTREACH
Not Applicable.

FISCAL IMPACT
The printing and distribution of the Power Content Label is estimated to cost $4,000. As this was included as part of the FY2024-2025 approved budget, no new appropriation is being requested at this time. The funding is outlined below:

Existing Appropriation
Amount Account String Funding Source
$4,000 43110-5820-GWP-4680 Electric Works Revenue
Fund

ENVIRONMENTAL REVIEW (CEQA/NEPA)
Not Applicable as the action herein is to note and file a report and is not a project for the purposes of the California Environmental Quality Act (CEQA).

CAMPAIGN DISCLOSURE
Not Applicable.

ALTERNATIVES TO STAFF RECOMMENDATION
Alternative 1: Consider any other alternative not proposed by staff. 15 of 559

48a
5 5
6 6

ADMINISTRATIVE ACTION
Submitted by:

Manuel Robledo, Interim General Manager - Glendale Water and Power Prepared by:

Scott K. Mellon, P.E., Assistant General Manager - Power Management Approved by:

Roubik R. Golanian, P.E., City Manager

EXHIBITS/ATTACHMENTS
Exhibit A: Annual Power Source Disclosure Report
Exhibit B: Annual Power Content Label
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M O T I O N
Moved by Council Member ________________________________, seconded by Council Member __________________________________, that the City Council hereby notes and files the Report dated November 19, 2024 by the Interim General Manager of Glendale Water & Power Department (GWP) regarding GWP’s Power Source Disclosure Report and Power Content Label for Calendar Year 2023.

Vote as follows:

Ayes:

Noes:

Absent:

Abstain:
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If you have questions, contact Power Source Disclosure (PSD) staff at [email protected] or (916) 639-0573.

NOTE: Information submitted in this report is not automatically held confidential. If your company wishes the information submitted to be considered confidential an authorized representative must submit an application for confidential designation (CEC-13), which can be found on the California Energy Commissions's website at https://www.energy.ca.gov/about/divisions-and-offices/chief-counsels-office.

WEBSITE URL FOR

PCL POSTING
www.GlendaleCA.gov/PowerContentLabel
Submit the Annual Report and signed Attestation in PDF format with the Excel version of the Annual Report to [email protected]. Remember to complete the Retail Supplier Name, Electricity Portfolio Name, and contact information above, and submit separate reports and attestations for each additional portfolio if multiple were offered in the previous year.

CITY, STATE, ZIP Clendale, CA, 91206
PHONE (818) 551-4685
EMAIL [email protected]
NAME Ralph Sakr
TITLE Power Systems Analyst
MAILING ADDRESS 141 N Glendale Avenue, Ste 450

CONTACT INFORMATION
2023 POWER SOURCE DISCLOSURE ANNUAL REPORT
For the Year Ending December 31, 2023

RETAIL SUPPLIER NAME
City of Glendale

ELECTRICITY PORTFOLIO NAME
Glendale Water and Power
Retail suppliers are required to use the posted template and are not allowed to make edits to this format. Please complete all requested information.

GENERAL INSTRUCTIONS
Exhibit A
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Schedule 1: Procurements and Retail Sales
Schedule 2: Retired Unbundled RECs
Schedule 3: Annual Power Content Label Data
GHG Emissions Factors
Specified Purchases: A Specified Purchase refers to a transaction in which electricity is traceable to specific generating facilities by any auditable contract trail or equivalent, such as a tradable commodity system, that provides commercial verification that the electricity claimed has been sold once and only once to retail consumers. Do not enter data in the grey fields. For specified purchases, include enter following information for each line item:

Facility Name - Provide the name used to identify the facility.

Fuel Type - Provide the resource type (solar, natural gas, etc.) that this facility uses to generate electricity.

Location - Provide the state or province in which the facility is located.

Identification Numbers - Provide all applicable identification numbers from the Western Renewable Energy Generation Information System (WREGIS), the Energy Information Agency (EIA), and the California Renewables Portfolio Standard (RPS).

Gross Megawatt Hours Procured - Provide the quantity of electricity procured in MWh from the generating facility.

Megawatt Hours Resold - Provide the quantity of electricity resold at wholesale.

Unspecified Power: Unspecified Power refers to electricity that is not traceable to specific generation sources by any auditable contract trail or equivalent, or to power purchases from a transaction that expressly transferred energy only and not the RECs associated from a facility. Do not enter procurements of unspecified power. The schedule will calculate unspecified power procurements automatically.

Complete this schedule by entering information about unbundled REC retirements in the previous calendar year.

Retail suppliers of electricity must complete this schedule by entering information about all power procurements and generation that served the identified electricity portfolio covered in this filing in the prior year. The schedule is divided into sections: directly delivered renewables, firmed-and-shaped imports, specified non-renewables, and procurements from ACSs. Insert additional rows as needed to report all procurements or generation serving the subject product. Provide the annual retail sales for the subject product in the appropriate space. At the bottom of Schedule 1, provide the retail suppliers’ other electricity end-uses that are not retail sales, such as transmission and distribution losses. Retail suppliers shall submit a purchase agreement or ownership arrangement documentation substantiating that any eligible firmed-and- shaped product for which it is claiming an exclusion was executed prior to January 1, 2019. Any retail supplier that offered multiple electricity portfolios in the prior year must submit separate Annual Reports for each portfolio offered.

Schedule 2 - Retired Unbundled Renewable Energy Credits (RECs) Schedule 3 - Annual Power Content Label Data
Asset-Controlling Supplier (ACS) Procurement Calculator PSD Attestation

INSTRUCTIONS
Schedule 1 - Procurements and Retail Sales

INTRODUCTION
Retail suppliers are required to submit separate Annual Reports for each electricity portfolio offered to California retail consumers in the previous calendar year. Enter the Retail Supplier Name and Electricity Portfolio Name at the top of Schedule 1, Schedule 2, Schedule 3, and the Attestation.

A complete Annual Report includes the following tabs:

PSD Intro
Instructions
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ACS Resource Mix Calculator
GHG Emissions Factors
Attestation
Retail suppliers may report specified purchases from ACS system power if the ACS provided its fuel mix of its specified system mix to the Energy Commission. Use the calculator to determine the resource-specific procurement quantities, and transfer them to Schedule 1.

This template provides the attestation that must be submitted with the Annual Report to the Energy Commission, stating that the information contained in the applicable schedules is correct and that the power has been sold once and only once to retail consumers. This attestation must be included in the package that is transmitted to the Energy Commission.

Please provide the complete Annual Report in Excel format and the complete Annual Report with signed attestation in PDF format as well.

This tab will be displayed for informational purposes only; it will not be used by reporting entities, since the emissions factors below auto-populate in the relevant fields on Schedules 1 & 3.

This schedule is provided as an automated worksheet that uses the information from Schedule 1 to calculate the power content and GHG emissions intensity for each electricity portfolio. The percentages calculated on this worksheet should be used for your Power Content Label.
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973,268
868,819
104,449
-
316,798
15,289
536,732
227,141

0.2334

DIRECTLY DELIVERED RENEWABLES
Facility Name Fuel Type
State or
Province WREGIS ID RPS ID N/A EIA ID
Gross MWh
Procured
MWh
Resold
Net MWh
Procured
Adjusted Net MWh
Procured
GHG Emissions
Factor (in MT
CO2e/MWh)
GHG Emissions (in
MT CO2e) N/A
Star Peak Geothermal Geothermal NV W13899 64292A 65773 49,961 49,961 49,961 0.0702 3,507 Townsite Solar Solar NV W12063 64813A 60654 160,167 1,289 158,878 158,878 - - Whitegrass No.1 [Geothermal] Geothermal NV W8098 63799A 63001 17,555 17,555 17,555 - - Tieton Dam Hydro Eligible hydro WA W222/W223 60735A 57496 15,851 15,851 15,851 - -

FIRMED-AND-SHAPED IMPORTS
Facility Name Fuel Type
State or
Province WREGIS ID RPS ID
EIA ID of
REC
Source
EIA ID of
Substitute Power
Gross MWh
Procured MWh Resold
Net MWh
Procured
Adjusted Net MWh
Procured
GHG Emissions
Factor (in MT
CO2e/MWh)
GHG Emissions
(in MT CO2e)
Eligible for
Grandfathered
Emissions?
Pebble Springs Wind OR W979 60693A 56789 Unspecified Power 38,892 38,892 38,892 0.4280 16,646 Yes High Winds - High Winds, LLC Wind CA W229 60726A 56075 Unspecified Power 13,198 13,198 13,198 0.4280 5,649 Yes Neal Hot Springs Unit #1 - Neal Hot Springs Geothermal Geothermal OR W3155 62427A 58022 Unspecified Power 17,757 17,757 17,757 0.4280 7,600 Rockland Wind Farm Wind ID W2445 61107A 57766 Unspecified Power 15,363 15,363 15,363 0.4280 6,575 Elkhorn Valley Wind Farm Wind OR W186 61034A 56623 Unspecified Power 11,202 11,202 11,202 0.4280 4,794 American Falls Solar II, LLC Solar ID W5375 63450A 60011 Unspecified Power 1,593 1,593 1,593 0.4280 682 American Falls Solar, LLC Solar ID W5376 63451A 60012 Unspecified Power 1,601 1,601 1,601 0.4280 685 Simcoe Solar, LLC Solar ID W5372 63447A 60748 Unspecified Power 1,266 1,266 1,266 0.4280 542

SPECIFIED NON-RENEWABLE PROCUREMENTS
Facility Name Fuel Type
State or
Province N/A N/A N/A EIA ID
Gross MWh
Procured MWh Resold
Net MWh
Procured
Adjusted Net MWh
Procured
GHG Emissions
Factor (in MT
CO2e/MWh)
GHG Emissions
(in MT CO2e) N/A
Griffith Energy Natural gas AZ 55124 640 640 640 0.3887 249 Intermountain Power Project (IPP) Coal UT 6481 82,382 67,093 15,289 15,289 0.9202 14,069 Palo Verde Nuclear Nuclear AZ 6008 112,308 8,283 104,025 104,025 - - Hoover Dam Large hydro AZ/NV 8902 46,215 - 46,215 46,215 - - Magnolia Power Plant Natural gas CA 56046 283,323 - 283,323 283,323 0.4040 114,462 Grayson Power Plant Natural gas CA 377 32,835 32,835 32,835 0.8877 29,148 Boundary Hydroelectric Large hydro WA 6433 445 445 445 - - Mid-C Hydro - Priest Rapids and Wanapum Dams (Grant County PUD) Large hydro WA 3888 16,893 16,893 16,893 - -

PROCUREMENTS FROM ASSET-CONTROLLING SUPPLIERS
Facility Name Fuel Type N/A N/A N/A N/A EIA ID
Gross MWh
Procured MWh Resold
Net MWh
Procured
Adjusted Net MWh
Procured
GHG Emissions
Factor (in MT
CO2e/MWh)
GHG Emissions
(in MT CO2e) N/A
Bonneville Power Administration (BPA) Large hydro BPA 17,364 17,364 0.0174 Bonneville Power Administration (BPA) Nuclear BPA 2,261 2,261 0.0174 Bonneville Power Administration (BPA) Other BPA 177 177 0.0174 3 Bonneville Power Administration (BPA) Unspecified Power BPA 955 955 0.0174 17 Tacoma Power Large hydro Tacoma Power 4,723 4,723 0.0218 103 Tacoma Power Nuclear Tacoma Power 297 297 0.0218 Tacoma Power Unspecified Power Tacoma Power 260 260 0.0218 END USES OTHER THAN RETAIL SALES MWh
Retail Sales (MWh)
Net Specified Procurement (MWh)
Unspecified Power (MWh)
Procurement to be adjusted
2023 POWER SOURCE DISCLOSURE ANNUAL REPORT
SCHEDULE 1: PROCUREMENTS AND RETAIL SALES
For the Year Ending December 31, 2023
City of Glendale
Glendale Water and Power
GHG Emissions Intensity (in MT CO2e/MWh)
Net Specified Natural Gas
Net Specified Coal & Other Fossil Fuels
Net Specified Nuclear, Large Hydro, Renewables, and ACS Power GHG Emissions (excludes grandfathered emissions)
Instructions: Enter information about power procurements underlying this electricity portfolio for which your company is filing the Annual Report.

Insert additional rows as needed. All fields in white should be filled out. Fields in grey auto-populate as needed and should not be filled out. For EIA IDs for unspecified power or specified system mixes from asset-controlling suppliers, enter "Unspecified Power", "BPA", or "Tacoma Power" as applicable. For specified procurements of ACS power, use the ACS Procurement Calculator to calculate the resource breakdown comprising the ACS system mix. Procurements of unspecified power must not be entered as line items below; unspecified power will be calculated automatically in cell N9. Unbundled RECs must not be entered on Schedule 1; these products must be entered on Schedule 2. At the bottom portion of the schedule, provide the other electricity end-uses that are not retail sales including, but not limited to transmission and distribution losses or municipal street lighting. Amounts should be in megawatt-hours. 21 of 559

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798

RETIRED UNBUNDLED RECS
Facility Name Fuel Type
State or
Province RPS ID Total Retired (in MWh)
Chase 4680 San Fernando Solar CA 62663A 332
Glendale Commnity College Solar CA 62057A 314
Glendale Unified School Solar CA 63938A 20
GWP-1 Aggregated Solar CA 62591R 15
GWP-2 Aggregated Solar CA 62592R 13
Kareco, Inc Solar CA 63939A 6
Windrose Glendale Prop LLC Solar CA 63952A 98
Total Retired Unbundled RECs
2023 POWER SOURCE DISCLOSURE ANNUAL REPORT
SCHEDULE 2: RETIRED UNBUNDLED RECS
For the Year Ending December 31, 2023
City of Glendale
Glendale Water and Power
INSTRUCTIONS: Enter information about retired unbundled RECs associated with this electricity portfolio. Insert additional rows as needed. All fields in white should be filled out. Fields in grey auto- populate as needed and should not be filled out.
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Adjusted Net
Procured (MWh)
Percent of Total
Retail Sales
Renewable Procurements 343,117 35.3% Biomass & Biowaste - 0.0% Geothermal 85,273 8.8%
Eligible Hydroelectric 15,851 1.6% Solar 163,338 16.8%
Wind 78,655 8.1%
Coal 15,289 1.6%
Large Hydroelectric 85,640 8.8% Natural gas 316,798 32.5%
Nuclear 106,583 11.0%
Other 177 0.0%
Unspecified Power 105,664 10.9%
Total 973,268 100.0%
973,268
515

0.1%
Total Retail Sales (MWh)
GHG Emissions Intensity (converted to lbs CO2e/MWh)
Percentage of Retail Sales Covered by Retired Unbundled RECs
2023 POWER SOURCE DISCLOSURE ANNUAL REPORT
SCHEDULE 3: POWER CONTENT LABEL DATA
For the Year Ending December 31, 2023
City of Glendale
Glendale Water and Power
Instructions: No data input is needed on this schedule. Retail suppliers should use these auto-populated calculations to fill out their Power Content Labels. 23 of 559

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Facility Name EIA ID or Proxy ID
GHG Emissions
Factor (in MT
CO2e/MWh)
Bonneville Power Administration (Asset-
Controlling Supplier) BPA 0.0174
Tacoma Power (Asset-Controlling Supplier) Tacoma Power 0.0218 Unspecified Power Unspecified Power 0.4280
Calciner 10601 0.9885
Searles Valley Minerals Inc. 10684 0.4944
Southeast Resource Recovery Facility (SERRF) 50837 1.6915 Turlock Irrigation District (TID), Almond Power
Plant 7315 0.5667
Sacramento Municipal Utility District (SMUD) ,
Campbell Power Plant 7552 0.4449
Air Products Wilmington Hydrogen Plant 55557 4.1665
Carson Hybrid Energy Storage LLC 10169 0.4705
California State University, San Jose 10548 0.6109
Chevron Products Company - El Segundo
Refinery, 90245 10213 2.4555
Double C Limited 50493 0.5458
Imperial Irrigation District (IID), El Centro
Generating Station 389 0.4591
El Segundo Energy Center, LLC 57901 0.4621
Calpine - Gilroy Cogen, L.P., Gilroy
Cogen_Peaker 55810 0.5360
Calpine - Gilroy Cogen, L.P., Gilroy
Cogen_Peaker 10034 0.5360
Pasadena Water and Power, Glenarm 422 0.6094
Pasadena Water and Power, Glenarm 420 0.6094
Goal Line LP, 92025 54749 0.4007
Grayson Power Plant 377 0.8877
ProEnergy - Greenleaf Energy Unit 2, LLC 10349 0.4184

INDEX OF GENERATOR-SPECIFIC GHG EMISSIONS

FACTORS
Instructions: This tab is for informational purposes only; it will not be used by reporting entities, since the emissions factors below auto-populate in the relevant fields on Schedules 1 & 3.
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Los Angeles Department of Water & Power-
Harbor Generating Station (LADWP) 399 0.5204
Harbor Cogeneration Company, LLC 50541 0.6740
Los Angeles Department of Water & Power-
Haynes Generating Station (LADWP) 400 0.4162
High Sierra Limited 50495 0.5522
PG&E Humboldt Bay Generating Station 246 0.4661
AES Huntington Beach, LLC 335 0.3715
AES Huntington Beach, LLC 62116 0.3715
New-Indy Ontario, LLC Linerboard Mill 10427 0.8537
KES Kingsburg L.P.--Kingsburg Cogeneration
Facility 10405 0.5560
Kern Front Limited 50494 0.5561
Kyocera International Inc. 10720 0.6063
Loma Linda University 10206 0.3946
Long Beach Generating Station 341 0.9003
Midway-Sunset Cogeneration 52169 0.2277
Torrance Refinery 50624 5.6030
Moss Landing Power Plant 260 0.3671
California State University, Channel Islands 50851 0.7036 OLS Energy Chino 50850 0.7497
Sacramento Municipal Utility District (SMUD) ,
Procter & Gamble Power Plant 7551 0.3988
Orange County Sanitation District - Plant 1 50696 0.5815 Redding Electric Utility - Redding Power
Generation 7307 0.4545
AES Redondo Beach LLC 356 0.9025
Eco Services - Martinez 52063 0.9841
Eco Services - Dominguez 52064 5.0879
SRI International Cogen Project 50537 0.3400
Rio Bravo Fresno 10767 0.0948
University of California, Santa Cruz, UCSC EH&S
Office 50064 0.4923
AltaGas Ripon Energy Inc. 50299 0.5291
McKittrick Limited 50612 0.4363
U.S. Borax, 93516 50115 0.3794
Phillips 66 Company - San Francisco Refinery 50119 0.7224 Malburg Generating Station 56041 0.4388
Yuba City Cogeneration Partners LP 52186 0.4129
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California Institute of Technology (CalTech) 10262 0.2604 Phillips 66 Company - Los Angeles Refinery -
Wilmington Plant 54451 2.2716
Calpine - Gilroy Energy Center, LLC, Feather
River 55847 0.5921
Calpine - Los Medanos Energy Center, LLC 55217 0.3458
La Paloma Generating Plant - GHG 55151 0.4099
Blythe Energy 55295 0.4233
Calpine - Metcalf Energy Center, LLC 55393 0.3929
Southern California Edison (SCE) -
Mountainview 358 0.3980
Calpine - Pastoria Energy Facility L.L.C. 55656 0.3739
Phillips 66 Company - San Francisco Carbon
Plant 50388 1.7950
Wildflower Energy, LP - Larkspur Energy
Facility, LLC 55542 0.5638
Tracy Combined Cycle Plant 55933 0.4618
SDG&E - Palomar Energy Center 55985 0.3804
California Power Holdings, LLC-Red Bluff
Facility, 96080 56184 0.5481
Turlock Irrigation District/ Walnut Energy
Center 56078 0.4499
Valero Refining Company - California, Benicia
Refinery and Benicia Asphalt Plant 55851 3.6846
CalPeak Power - Panoche, LLC 55508 0.5919
CalPeak Power - Vaca Dixon, LLC 55499 0.5702
Calpine - Goose Haven Energy Center, Peaker 10350 0.5613 Riverside Public Utilities - Clearwater Facility 56356 0.4699 Braun Medical Inc 50200 0.4696
Riverside Public Utilities - Riverside Energy
Resource Center 56143 0.5878
Southern California Edison (SCE) - Mira Loma
Peaker 56473 0.5381
Coso Energy Developers (BLM E&W) -
Geothermal 10875 0.3160
CalEnergy Operating Corporation - J J Elmore -
Geothermal 10634 0.0178
CalEnergy Operating Corporation - J M Leathers
- Geothermal 10631 0.0846
CalEnergy Operating Corporation - Region 1 -
Geothermal 10878 0.0768
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CalEnergy Operating Corporation - Region 1 -
Geothermal 10879 0.0768
CalEnergy Operating Corporation - Region 1 -
Geothermal 10759 0.0768
CalEnergy Operating Corporation - Region 1 -
Geothermal 54996 0.0768
CalEnergy Operating Corporation - Region 1 -
Geothermal 55983 0.0768
CalEnergy Operating Corporation - Region 2 -
Geothermal 55984 0.0732
CalEnergy Operating Corporation - Region 2 -
Geothermal 10632 0.0732
CalEnergy Operating Corporation - Region 2 -
Geothermal 50210 0.0732
Sycamore Cogeneration Facility 50134 0.3396
Bear Mountain Limited 10649 0.4903
Shadow Wolf Energy - Placerita 52096 0.6387
Badger Creek Limited 10650 0.5064
Bridge Energy, LLC 56090 1.0335
Martinez Refining Company LLC 54912 2.6014
Sunrise Power Company 55182 0.3769
University of California, Los Angeles, UCLA 52073 0.2685 Los Angeles Department of Water & Power-
Scattergood Generating Station (LADWP) 404 0.4019
Central Contra Costa Sanitary District 57573 1.3407
Modesto Irrigation District (MID) - Woodland
Generation Station, 95351 7266 0.5039
Live Oak Limited 54768 0.5112
California Power Holdings, LLC-Chowchilla
Facility, 95360 56185 0.5502
San Jose/Santa Clara Regional Wastewater
Facility 56080 0.4672
Calpine - Los Esteros Critical Energy Facility, LLC 55748 0.4778 MAGTFTC MCAGCC Twentynine Palms 58914 0.2724
Calpine - Yuba City Energy Center (Gilroy
Energy Center, LLC) 55813 0.5727
Grade 6 Oil, LLC 54410 1.4108
Spreckels Sugar Company, Inc.- Brawley 57916 0.3733
Los Angeles Refinery (LAR) 50216 0.9499
Los Angeles Refinery (LAR) 50530 0.9499
Chula Vista Energy Center 55540 0.9562
Crockett Cogeneration Project, LP 55084 0.3253
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Covanta - Stanislaus, Inc 50632 1.9574
Roseville Electric, Roseville Energy Park 56298 0.4514
Luz Solar Partners LTD VIII & IX 10446 0.0015
University of California, Irvine 57122 0.3000
Calpine - King City Cogen, LLC, King City
Cogen_Peaker 10294 0.4935
Calpine - King City Cogen, LLC, King City
Cogen_Peaker 55811 0.4935
University of California, San Diego, UCSD 57584 0.4223
Imperial Irrigation District (IID), Niland Gas
Turbine Plant 56569 0.5325
AES Alamitos, LLC 315 0.4215
AES Alamitos, LLC 62115 0.4215
Los Angeles International Airport (LAX) 58258 0.2544
Los Angeles Department of Water & Power-
Valley Generating Station (LADWP) 408 0.3804
Martinez Renewable Fuel Facility 10342 0.3328
Wildflower Energy, LP - Indigo Generation, LLC 55541 0.5863 Oakland Power Plant 6211 1.0328
E.F. Oxnard LLC 10776 0.5220
New-Indy Oxnard LLC 57585 0.3043
Ormond Beach Power, LLC 350 0.6431
Modesto Irrigation District - Ripon Generation
Station, 95366 56135 0.6543
Henrietta Peaker Plant 55807 0.5430
Chevron Products Company - Richmond
Refinery, 94802 52105 1.5037
Chevron Products Company - Richmond
Refinery, 94802 52109 1.5037
California State University, San Diego 50061 0.3915
Qualcomm, Inc. - Morehouse Facility 59456 0.4175
SDG&E - Miramar Energy Facility 56232 0.5516
CalPeak Power - Border 55510 0.5879
University of California, San Francisco 58198 0.3412
Calpine - O.L.S. Energy - Agnews Inc. 95134 50748 0.5085 Algonquin Power Sanger, LLC 57564 0.3797
Silicon Valley Power (SVP), City of Santa Clara ,
DVR 56026 0.4372
Silicon Valley Power (SVP), City of Santa Clara ,
Cogen 7232 0.6282
High Desert Power Project, LLC 55518 0.4048
Calpine - CCFC Sutter Energy, LLC 55112 0.4004
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Kern Energy (refinery) 58100 4.4347
Kern River Cogeneration Facility 10496 0.3216
Salinas River Cogeneration Facility 50865 0.3980
CP Kelco San Diego 52147 0.6086
Qualcomm, Inc. - Pacific Center Facility 59458 0.3125
Qualcomm, Inc. - Pacific Center Facility 59457 0.3125
Calpine - Creed Energy Center, LLC 55625 0.5962
Calpine - Delta Energy Center, LLC 55333 0.3875
Calpine - Geysers Power Company, LLC -
Geothermal 52158 0.0351
Calpine - Geysers Unit 5-20 286 0.0351
Calpine - Sonoma California Geothermal 510 0.0351
Calpine - Calistoga Power Plant 50066 0.0351
Calpine - Gilroy Energy Center, LLC, Riverview
Peaker 55963 0.5557
Northern California Power Agency -
Geothermal Plant No. 1 7368 0.0537
Northern California Power Agency -
Geothermal Plant No. 2 7369 0.0890
Southern California Edison (SCE) - Grapeland
Hybrid 56472 0.6134
Southern California Edison (SCE) - Barre Peaker 56474 0.5422 Southern California Edison (SCE) - Center
Hybrid 56475 0.5846
Hanford Energy Park Peaker 55698 0.5497
Fresno Cogeneration Partners, LP 10156 0.6210
The P&G Paper Products Co. 50464 0.4039
Lockheed Martin Corporation - Sunnyvale 57808 19.1212
CalPeak Power - Enterprise 55513 0.5750
SDG&E - Cuyamaca Peak Energy Plant 55512 0.6053
City of Colton - Generation 55951 0.6124
Coso Power Developers (Navy II) - Geothermal 10874 0.2852 Coso Finance Partners (Navy I) - Geothermal 10873 0.1400 Southern California Edison (SCE) - Pebbly Beach 6704 0.8123 Malaga Power, LLC 56239 0.5515
Panoche Energy Center, LLC 56803 0.4999
PG&E Gateway Generating Station 56476 0.4007
Midway Peaking, LLC 56639 0.6281
Calpine - Otay Mesa Energy Center 55345 0.3816
PG&E Colusa Generating Station 56532 0.3975
Canyon Power Project (CPP) 57027 0.5654
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High Sierra Cogeneration 57977 0.4001
Chevron AAPG 745 San Joaquin Basin 52086 0.9749
Chevron AAPG 745 San Joaquin Basin 52082 0.9749
Chevron AAPG 745 San Joaquin Basin 52076 0.9749
Chevron AAPG 745 San Joaquin Basin 52107 0.9749
Chevron AAPG 745 San Joaquin Basin 50751 0.9749
Chevron AAPG 745 San Joaquin Basin 52081 0.9749
Chevron AAPG 745 San Joaquin Basin 52085 0.9749
Chevron AAPG 745 San Joaquin Basin 52104 0.9749
California Resources Elk Hills, LLC - 35R Gas
Plant 55400 0.6925
Aera Energy San Joaquin Basin 50750 2.4909
Aera Energy San Joaquin Basin 50752 2.4909
Aera Energy San Joaquin Basin 52077 2.4909
Aera Energy Coastal Basins 55184 2.3732
Naval Medical Center - San Diego 50963 0.8266
Orange Grove Energy Center 56914 0.5844
California Resources Production Corporation -
760 Los Angeles Basin 56051 0.8339
BWP/MPP Electricity Generating Facilities at
164 W. Magnolia 6013 0.4040
BWP/MPP Electricity Generating Facilities at
164 W. Magnolia 56077 0.4040
BWP/MPP Electricity Generating Facilities at
164 W. Magnolia 56046 0.4040
BWP/MPP Electricity Generating Facilities at
164 W. Magnolia 7987 0.4040
Escondido Energy Center, LLC 55538 0.5770
El Cajon Energy, LLC 57001 0.5823
Sentinel Peak Resources - SJV Basin Facility 54447 4.6355 Sentinel Peak Resources - SJV Basin Facility 54449 4.6355 Signal Hill Petroleum Facilities 57702 1.1634
Berry Petroleum Company - San Joaquin Basin 50622 1.1434 Berry Petroleum Company - San Joaquin Basin 50170 1.1434 Berry Petroleum Company - San Joaquin Basin 62176 1.1434 Mariposa Energy LLC 57483 0.5676
Lodi Energy Center 57978 0.3944
Lodi Energy Center 7449 0.3944
Marsh Landing Generating Station 57267 0.60530
Walnut Creek Energy, LLC 57515 0.50140
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Sentinel Energy Center, LLC 57482 0.53890
Southern California Edison (SCE) - McGrath
Peaker 56471 0.57010
Hudson Ranch Power I - Geothermal 57475 0.0588
Kaweah Delta Medical Center 10042 854.1424
Saint Agnes Medical Center 54800 0.1975
GH Camarillo, LLC 58432 0.6574
Hoag Memorial Hospital Presbyterian 58223 0.4229
Olive View Medical Center, Los Angeles County
Department of Health Services 10884 0.3872
Rady Children's Hospital San Diego 10175 0.5147
Calpine - Russell City Energy Center 56467 0.3930
Ivanpah Solar Electric Generating System 57074 0.0596
Ivanpah Solar Electric Generating System 57073 0.0596
Ivanpah Solar Electric Generating System 57075 0.0596
Delano Energy Center, LLC 58122 0.5657
Ormat Nevada, Inc. / ORNI 18 North Brawley -
Geothermal 56832 0.5963
University of California, Berkeley 50849 0.3321
Sharp Grossmont Hospital 10115 0.3850
Pio Pico Energy Center 57555 0.5261
Carlsbad Energy Center Project 59002 0.5382
Equinix Great Oaks - Bloom Energy Servers 62702 0.3776
Equinix Great Oaks - Bloom Energy Servers 63704 0.3776
Equinix Great Oaks - Bloom Energy Servers 63708 0.3776
Equinix Great Oaks - Bloom Energy Servers 60223 0.3776
Equinix Lundy - Bloom Energy Servers 62703 0.3654
Equinix Caspian - Bloom Energy Servers 62671 0.3765
Equinix Duane - Bloom Energy Servers 63705 0.3877
Keysight Technologies Inc - Bloom Energy
Servers 65199 0.3805
Kaiser Permanente - Bloom Energy Servers 62701 0.3682
Apple Inc - Bloom Energy Servers 59557 0.4426
IBE Project - Bloom Energy Servers 60224 0.4849
IBE Project - Bloom Energy Servers 62697 0.4849
Stanton Energy Reliability Center 60698 0.6080
Illumina - Bloom Energy Servers 63603 0.3840
Genentech - Bloom Energy Servers 60844 0.3786
Kaiser LA Medical Center - Bloom Energy
Servers 66146 0.3768
31 of 559

Version: April 2024
Burney Forest Products 10652 0.0705
Encina Water Pollution Control Facility 10026 0.3579
HL Power Company LP 10777 0.0375
Miramar - MM and Miramar Energy 55094 0.0033
Humboldt Sawmill Company 50049 0.0501
Sierra Pacific Industries (SPI) - Burney 50110 0.0092
Rio Bravo Rocklin 10772 0.0558
Wadham Energy Ltd Partnership 50293 0.0226
Waste Management - Altamont Landfill 50571 0.0055
Brea Power Facility 58007 0.0029
LACSD - Puente Hills Landfill 10472 0.0032
MM Lopez Energy LLC 55161 0.0027
Sierra Pacific Industries (SPI) - Anderson, 96007 59658 0.0102 Sonoma County Landfill Gas to Energy 55752 0.0036
Sonoma County Landfill Gas to Energy 55753 0.0036
Sonoma County Landfill Gas to Energy 55880 0.0036
Sacramento Municipal Utility District (SMUD) ,
Carson Power Plant 7527 0.4228
Shasta Sustainable Resource Management 50881 0.0297
Sacramento Municipal Utility District (SMUD) ,
Cosumnes Power Plant 55970 0.4085
Kiefer Landfill, Department of Waste
Management and Recycling 55766 0.0058
MM Yolo Power LLC 54567 0.0000
Mt. Poso Cogeneration Company 54626 0.0394
Collins Pine Co. 10661 0.0106
Orange County Sanitation District - Plant 2 52099 0.0897 Pacific Ultrapower Chinese 50560 0.0423
LACSD - Calabasas Landfill 57163 0.0042
Monterey Regional Waste Management District 10748 0.0029 Sierra Pacific Industries (SPI) - Quincy Division 50112 0.0479 MM West Covina LLC 54015 0.0058
LACSD - Joint Water Pollution Control Plant 10091 0.1508 Woodland Biomass Power, LLC 10836 0.0336
East Bay Municipal Utility District 56036 0.0118
East Bay Municipal Utility District 57696 0.0118
City of San Diego, Public Utilities Dept, Point
Loma Treatment Plant 50492 0.0145
Ameresco Santa Cruz 56428 0.0033
32 of 559

Version: April 2024
Ameresco Half Moon Bay 56895 0.0028
Ampersand Chowchilla Biomass, LLC, 93610 56706 0.0309
Merced Power, LLC, 95340 56707 0.0317
Sierra Pacific Industries (SPI) - Lincoln 10144 0.0109
Sierra Pacific Industries (SPI) - Sonora 54517 0.0733
G2 Energy Ostrom Road, LLC 57133 0.0029
Sycamore Energy LLC 10387 0.0070
Roseburg Forest Products 56469 0.0119
MM Prima Deshecha Energy LLC 55601 0.0031
Energy 2001, Placer WRSL 57362 0.0065
Ameresco Keller Canyon 56897 0.0028
Ameresco Chiquita Energy LLC 56898 0.0043
DTE Stockton, LLC 54238 0.0289
GenPower Lincoln Landfill Power Plant 57988 0.0061
City of San Diego, Public Utilities Dept, North
City Water Reclamation Plant 60571 0.0151
City of San Diego, Public Utilities Dept, North
City Water Reclamation Plant 55602 0.0151
Sunshine Gas Producers, LLC 58429 0.0033
San Francisco Southeast Treatment Plant 57971 0.0723
Ameresco Vasco Road 58435 0.0027
Ameresco San Joaquin LLC 58436 0.0027
Ameresco Forward LLC 58437 0.0028
Bowerman Power LFG, LLC 59461 0.0029
Potrero Hills Energy Producers, LLC 59952 0.0021
Hyperion Water Reclamation Plant 60960 0.2629
Waste Management - Redwood Landfill, Inc. 59299 0.0032
Afton Generating Station 55210 0.4479
Agua Fria Generating Station 141 0.6340
Albeni Falls [Hydro] 851 0.0000
American Falls Solar 60011 0.0000
American Falls Solar II 60012 0.0000
Anderson Ranch [Hydro] 6395 0.0000
Apache Generating Station 160 0.8479
Apache Solar 60964 0.0000
Apex Generating Station 55514 0.3656
Aragonne Wind 56336 0.0000
Arlington Valley Energy Facility 55282 0.3947
Arlington Valley Solar II 57680 0.0000
Arlington Wind 56855 0.0000
Badger 1 [Solar] 58262 0.0000
Beaver 8073 0.5384
Bennett Mountain Power 55733 0.5909
33 of 559

Version: April 2024
Beowawe Power [Geothermal] 10287 0.0605
Big Cliff [Hydro] 3074 0.0000
Big Horn II [Wind] 57319 0.0000
Big Horn PPM [Wind] 56361 0.0000
Biglow Canyon Wind (Phase 1) 56485 0.0000
Biglow Canyon Wind (Phase 2) 56485 0.0000
Biglow Canyon Wind (Phase 3) 56485 0.0000
Black Canyon [Hydro] 6396 0.0000
Black Mountain Generating Station 56482 0.5584
Blue Mountain Geothermal Project 56982 0.0000
Boise River Diversion [Hydro] 6397 0.0000
Bonneville Dam 3075 0.0000
Boulder Park 8022 0.4933
Boundary Hydro 6433 0.0000
Box Canyon Dam (WA) 3891 0.0000
Broadview Energy JN [Wind] 60145 0.0000
Broadview Energy KW [Wind] 60152 0.0000
Brownlee [Hydro] 811 0.0000
Cabinet Gorge [Hydro] 833 0.0000
Caithness Shepherd's Flat - Horseshoe Bend
[Wind] 57550 0.0000
Caithness Shepherd's Flat - North Hurlburt
[Wind] 57526 0.0000
Caithness Shepherd's Flat - South Hurlburt
[Wind] 57549 0.0000
Carty Generating Station 58503 0.3887
Cedar Creek II [Wind] 57210 0.0000
Cedar Creek Wind 56371 0.0000
Cedar Point Wind 57315 0.0000
Chandler [Hydro] 6406 0.0000
Chehalis 55662 0.4086
Chief Joseph [Hydro] 3921 0.0000
Chino Solar Valley 57560 0.0000
Cholla Power Station 113 1.1895
Chuck Lenzie Station 55322 0.4094
CJ Strike [Hydro] 812 0.0000
Clark Station 2322 0.5297
Clines Corners Wind 64054 0.0000
Colstrip 6076 1.0025
Columbia Generating Station [Nuclear] 371 0.0000
Condon Wind 55739 0.0000
Coolidge Generation Station 56948 0.5659
Copper Mountain Solar 1 (CM10) 56944 0.0000
Copper Mountain Solar 2 (CMS2) 58017 0.0000
Copper Mountain Solar 3 58915 0.0000
34 of 559

Version: April 2024
Copper Mountain Solar 4 (CMS4) 59814 0.0000
Coronado Generating Station 6177 1.1593
Cotton Center Solar Hybrid 57561 0.0000
Cougar [Hydro] 3076 0.0000
Cowiltz River Project (Mayfield & Mossyrock
Dams) 3917 0.0000
Cowlitz Falls [Hydro] 7427 0.0000
Coyote Springs II 7931 0.3649
Currant Creek 56102 0.4040
Cushman Hydro Project (No. 1 & No. 2 Dams) 3914 0.0000
Dave Johnston 4158 1.1603
Desert Basin Generating Station 55129 0.4255
Desert Star [Solar] 59444 0.0000
Desert Star Energy Center (fka Eldorado
Energy) 55077 0.4158
Detroit [Hydro] 3077 0.0000
Dexter [Hydro] 3078 0.0000
Don A. Campbell (Phase 2) Geothermal 60419 0.0000
Don A. Campbell (Wild Rose) Geothermal 58533 0.0000
Duran Mesa [Wind] 64065 0.0000
Dworshak [Hydro] 840 0.0000
El Cabo Wind 58098 0.0000
Elkhorn Valley Wind 56623 0.0000
Eltopia Branch Canal 4.6 Hydro 56696 0.0000
Encogen Generating Station 7870 0.4855
Evander Andrews Power Complex 7953 0.5964
Ferndale Generating Station 54537 0.4193
Foothills Solar 57997 0.0000
Fort Churchill Station 2330 0.6318
Foster [Hydro] 6552 0.0000
Four Corners Power Plant 2442 0.9928
FPL Energy Stateline II (Vansycle II) [Wind] 58324 0.0000 FPL Energy Vansycle (Stateline 1&2) [Wind] 55989 0.0000 Frank Tracy Station 2336 0.4288
Frederickson Power LP 55818 0.3827
Frederickson PSE 99 0.7677
Fredonia Generating Station 607 0.6487
Gadsby 3648 0.9912
Gala Solar (Solar Star Oregan II) 61048 0.0000
Galena 2 Geothermal 56540 0.0000
Galena 3 Geothermal 56541 0.0000
Gila Bend Hybrid [Solar] 59020 0.0000
35 of 559

Version: April 2024
Glacier Wind (Naturener) 57049 0.0000
Glen Canyon Dam 153 0.0000
Goldendale Generating Station 55482 0.3729
Goshen Phase II [Wind] 57211 0.0000
Grady Wind 60317 0.0000
Grand Coulee [Hydro] 6163 0.0000
Grand View PV Solar Two 60068 0.0000
Grays Harbor Energy 7999 0.3863
Green Peter [Hydro] 3080 0.0000
Green Springs [Hydro] 6403 0.0000
Griffith Energy 55124 0.3887
H. Wilson Sundt Generating Station (fka
Irvington Generating Station) 126 0.5496
Harquahala Generating Project 55372 0.3794
Harry Allen Station 7082 0.4040
Harvest Wind 57152 0.0000
Hay Canyon Wind 56790 0.0000
Headgate Rock Dam 7179 0.0000
Hells Canyon [Hydro] 3013 0.0000
Hermiston 54761 0.3877
Hermiston Power 55328 0.3946
Higgins Generating Station 55687 0.4055
High Lonesome Mesa [Wind] 56945 0.0000
Hills Creek [Hydro] 3081 0.0000
Holter Dam 2186 0.0000
Hoover Dam 154 0.0000
Hopkins Ridge Wind 56255 0.0000
Horse Butte Wind 57890 0.0000
Horse Mesa HM4 [Hydro] 145 0.0000
Hungry Horse [Hydro] 2203 0.0000
Hunter 6165 0.9988
Huntington 8069 0.9988
Hyder Hybrid [Solar] 57563 0.0000
Hyder II Hybrid [Solar] 58383 0.0000
Ice Harbor [Hydro] 3925 0.0000
ID Solar 1 60445 0.0000
Intermountain Power Project (IPP) 6481 0.9202
Jim Bridger Total Plant 8066 1.0472
John Day [Hydro] 3082 0.0000
Juniper Canyon Wind 57320 0.0000
Kerr [Hydro] 2188 0.0000
Kittitas Valley Wind (Sagebrush) 56858 0.0000
Klamath Falls Cogen 55103 0.4033
Klondike Wind I 55871 0.0000
Klondike Wind II 56359 0.0000
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Version: April 2024
Klondike Wind III 56468 0.0000
Klondike Wind IIIA 56468 0.0000
Kyrene Generating Station 147 0.3815
La Joya Wind 61044 0.0000
La Luz Generating Station 58284 0.5965
Lake Chelan Hydro 6424 0.0000
Lake Side 56237 0.3887
Lancaster 55179 0.3820
Langley Gulch Power Plant 57028 0.3747
Las Vegas Generating Station 10761 0.4778
Leaning Juniper II [Wind] 57333 0.0000
Libby (USACE) [Hydro] 6172 0.0000
Limon Wind I 58126 0.0000
Limon Wind II 58127 0.0000
Limon Wind III 59083 0.0000
Linden Wind (aka Linden Ranch Wind) 57635 0.0000
Little Falls [Hydro] 3866 0.0000
Little Goose [Hydro] 3926 0.0000
Logan Wind 56613 0.0000
Long Lake [Hydro] 3867 0.0000
Lookout Point [Hydro] 3083 0.0000
Lordsburg Generating Station 7967 0.5686
Lost Creek [Hydro] 6174 0.0000
Lower Baker [Hydro] 3855 0.0000
Lower Granite [Hydro] 6175 0.0000
Lower Monumental [Hydro] 3927 0.0000
Lower Snake River Wind 57195 0.0000
Lucky Peak Power Plant Project [Hydro] 10014 0.0000
Luke Solar 57324 0.0000
Luna Energy Facility 55343 0.3794
Luning Solar 61084 0.0000
Main Canal Headworks Hydro 56698 0.0000
McGinness Hills 3 Geothermal 57446 0.0000
McNary [Hydro] 3084 0.0000
Mesquite Solar 1 57707 0.0000
Mesquite Solar 2 60307 0.0000
Mid-C Hydro - Priest Rapids & Wanapum Dams
(Grant County PUD) 3887 0.0000
Mid-C Hydro - Rock Island (Chelan County PUD) 6200 0.0000 Mid-C Hydro - Rocky Reach (Chelan County
PUD) 3883 0.0000
Mid-C Hydro - Wells (Douglas County PUD) 3886 0.0000
Milford I Wind 57079 0.0000
37 of 559

Version: April 2024
Milford II Wind 57107 0.0000
Minidoka [Hydro] 6398 0.0000
Mint Farm Generation Station 55700 0.4073
Moapa Southern Paiute Solar 57859 0.0000
Mohave County Wind 63114 0.0000
Monroe Street HED [Hydro] 9095 0.0000
Montague Wind 58099 0.0000
Mormon Flat [Hydro] 148 0.0000
Murphy Flat Solar 60009 0.0000
Naughton 4162 1.0281
Neal Hot Springs Geothermal 58022 0.0000
Nebo Power Station 56177 0.4563
New Mexico Wind Energy Center 56097 0.0000
Nine Mile HED [Hydro] 3869 0.0000
Nisqually River Project (Alder & LaGrande
Dams) 3913 0.0000
North Loop Generating Station 6088 0.7370
Northern Colorado Wind I 57290 0.0000
Noxon Rapids [Hydro] 2199 0.0000
Ocotillo 116 0.5399
Old Lahontan Hydro 6521 0.0000
Orchard Ranch Solar 60010 0.0000
Oxbow (Oregon) [Hydro] 3014 0.0000
Palisades [Hydro] 850 0.0000
Palo Verde Nuclear 6008 0.0000
Paloma Solar Hybrid 57562 0.0000
Palouse Wind 57530 0.0000
Parker-Davis Project [Hydro] 447 0.0000
Patua Geothermal 58319 0.0000
Patua Solar 58319 0.0000
Pebble Springs [Wind] 56789 0.0000
Peetz Table Wind 56563 0.0000
Pelton Round Butte [Hydro] 3048 0.0000
Perrin Ranch Wind 58155 0.0000
Pleasant Valley Wind 56093 0.0000
Port Westward 1 56227 0.3708
Port Westward 2 58266 0.4601
Post Falls Hydro 835 0.0000
Potholes East Canal 66.0 Hydro 56697 0.0000
Potholes East Canal Headworks Powerplant
[Hydro] 7113 0.0000
Prescott Airport [Solar] 56228 0.0000
Prescott Solar 58147 0.0000
Raft River Geothermal - GE 1 56317 0.0000
Rathdrum 7456 0.5665
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Version: April 2024
Rattlesnake Flat Wind 62936 0.0000
RE Ajo 1 [Solar] 57795 0.0000
RE Bagdad Solar I 57790 0.0000
RE Gillespie 1 [Solar] 58501 0.0000
Red Cloud Wind 63981 0.0000
Red Hawk Power Station CC Natural Gas 55455 0.3787
Red Mesa Wind 57357 0.0000
Red Rock Solar 60467 0.0000
Reeves Generating Station 2450 0.8218
Richard Burdette Power Plant [Geothermal] 56321 0.0000
Rim Rock Wind (Naturener) 57995 0.0000
Roosevelt [Hydro] 149 0.000
Ross Dam 6202 0.000
Roza [Hydro] 6407 0.0000
Saddle Mountain Solar I 58213 0.0000
Saguaro 118 0.7520
San Juan 2451 1.2061
Santan Generating Station 8068 0.4122
Silver State Solar - South 58644 0.0000
Silverhawk Station 55841 0.4223
Simcoe Solar 60748 0.0000
Skookumchuck Wind 63205 0.0000
Smith Falls Hydro 54249 0.0000
Snoqualmie [Hydro] 3860 0.0000
Solana [Solar] 56812 0.0000
South Point Energy Center 55177 0.4079
Spring Canyon [Wind] 56320 0.0000
Springerville Generating Station 8223 1.0437
Stampede [Hydro] 7066 0.0000
Star Point [Wind] 57096 0.0000
Steamboat Hills Geothermal 50654 0.0000
Steamboat II [Geothermal] 54665 0.0000
Steamboat III [Geothermal] 54666 0.0000
Stewart Mountain [Hydro] 150 0.0000
Sumas Power Plant 54476 0.4485
Summer Falls Power Plant Hydro 56695 0.0000
Sun Peak Generating Station 54854 0.7009
Sun Streams [Solar] 60827 0.0000
Sundance 55522 0.5651
Sunshine Valley Solar 59826 0.0000
Swift No. 1 [Hydro] 3850 0.0000
Tecolote Wind 64066 0.0000
Terra-Gen Dixie Valley [Geothermal] 52015 0.0635
The Dalles [Hydro] 3895 0.0000
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Version: April 2024
Thermo No. 1 Geothermal (Raser Technologies) 57353 0.0000 Tieton Dam Hydro 57496 0.0000
Townsite Solar 60654 0.0000
Transalta Centralia Generation 3845 1.1188
TS Power Plant 56224 1.1553
Tucannon River Wind 58571 0.0000
Tungsten Mountain Geothermal 60785 0.0000
Turquoise Liberty Solar - Phase 1 62980 0.0000
Twin Buttes [Wind] 56460 0.0000
Upper Baker [Hydro] 3861 0.0000
Upper Falls Hydro 9096 0.0000
Valencia Energy Center 55802 0.6174
Valencia Power Plant 6515 0.6885
Vantage Wind 57188 0.0000
Veyo Heat Recovery Project [Waste heat] 60421 0.0000
West Phoenix 117 0.4507
West Valley Generation Project 55622 0.5922
White Creek Wind 56487 0.0000
Whitegrass No. 1 [Geothermal] 63001 0.0000
Whitehorn Generating Station 6120 0.7917
Wild Horse Wind 56322 0.0000
Willow Creek Wind 56952 0.0000
Windy Flats Wind 57159 0.0000
Windy Point/Flats - Phase 1 (Tuolumne Wind
Project) 56702 0.0000
Wy'East Solar 61345 0.0000
Wynoochee River Project [Hydro] 7127 0.0000
Wyodak 6101 1.2379
Yale [Hydro] 3852 0.0000
Yucca 120 0.6585
Yuma Cogen Associates 54694 0.5123
Big Sky Dairy Digester 57393 0.5464
Clearwater Paper Corp. - Lewiston 50637 0.0379
Desert View Power [Biomass] 10300 0.0399
Kettle Falls Woodwaste Plant 550 0.0358
Longview Washington Pulp & Paper Mill 54562 0.0654
Rock Creek Dairy (New Energy One) [Digester
Gas] 58142 0.0032
Seneca Sustainability Energy [Biomass] 57457 0.0213
Trans-Jordan Generating Station (Landfill Gas) 56853 0.0029 WestRock - Tacoma (fka Simpson Biomass) 57099 0.0481
Rollins 34 0.0000
40 of 559

Version: April 2024
Venice Hydro 72 0.0000
South Consolidated 100 0.0000
J S Eastwood 104 0.0000
Davis Dam 152 0.0000
Lake Creek Dam 159 0.0000
Turlock Lake 161 0.0000
Hickman 162 0.0000
Volta 2 180 0.0000
Alta Powerhouse 214 0.0000
Angels 215 0.0000
Balch 1 217 0.0000
Balch 2 218 0.0000
Belden 219 0.0000
Bucks Creek 220 0.0000
Butt Valley 221 0.0000
Caribou 1 222 0.0000
Caribou 2 223 0.0000
Chili Bar 225 0.0000
Coleman PH 227 0.0000
Cow Creek 229 0.0000
Cresta 231 0.0000
De Sabla 232 0.0000
Deer Creek PH 233 0.0000
Drum 1 235 0.0000
Drum 2 236 0.0000
Dutch Flat 237 0.0000
El Dorado 238 0.0000
Electra 239 0.0000
Haas 240 0.0000
Halsey 241 0.0000
Hat Creek 1 243 0.0000
Hat Creek 2 244 0.0000
James B Black 249 0.0000
Kilarc 253 0.0000
Kings River PH 254 0.0000
Merced Falls 258 0.0000
Murphys 261 0.0000
Narrows PH 262 0.0000
Phoenix 264 0.0000
Pit 1 265 0.0000
Pit 3 266 0.0000
Pit 4 267 0.0000
Pit 5 268 0.0000
Pit 6 269 0.0000
Pit 7 270 0.0000
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Version: April 2024
Poe 272 0.0000
Potter Valley 274 0.0000
Rock Creek 275 0.0000
San Joaquin 2 276 0.0000
Salt Springs 279 0.0000
South 280 0.0000
Spaulding 1 281 0.0000
Spaulding 2 282 0.0000
Spaulding 3 283 0.0000
Spring Gap 284 0.0000
Stanislaus 285 0.0000
Tiger Creek 287 0.0000
Volta 1 290 0.0000
West Point PH 291 0.0000
Wise 292 0.0000
A G Wishon 293 0.0000
Copco 1 294 0.0000
Copco 2 295 0.0000
Fall Creek 296 0.0000
Iron Gate 297 0.0000
Drop 5 314 0.0000
Sepulveda Canyon 316 0.0000
Big Creek 1 317 0.0000
Big Creek 2 318 0.0000
Big Creek 3 319 0.0000
Big Creek 4 320 0.0000
Big Creek 8 321 0.0000
Big Creek 2A 322 0.0000
Bishop Creek 2 323 0.0000
Bishop Creek 3 324 0.0000
Bishop Creek 4 325 0.0000
Bishop Creek 5 326 0.0000
Bishop Creek 6 327 0.0000
Fontana 332 0.0000
Kaweah 2 336 0.0000
Kaweah 1 337 0.0000
Kaweah 3 338 0.0000
Kern River 3 339 0.0000
Kern River 1 340 0.0000
Lundy 342 0.0000
Mammoth Pool 344 0.0000
Poole 353 0.0000
Portal 354 0.0000
Rush Creek 357 0.0000
Santa Ana 1 361 0.0000
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Version: April 2024
Santa Ana 3 363 0.0000
Pardee 376 0.0000
Dion R Holm 380 0.0000
Moccasin 381 0.0000
R C Kirkwood 382 0.0000
Drop 2 (CA) 385 0.0000
Drop 3 (CA) 386 0.0000
Drop 4 387 0.0000
Pilot Knob 388 0.0000
Big Pine Creek 391 0.0000
Castaic 392 0.0000
Control Gorge 393 0.0000
Cottonwood 394 0.0000
Foothill 396 0.0000
Franklin (CA) 397 0.0000
Haiwee 398 0.0000
Middle Gorge 401 0.0000
Pleasant Valley Hydro 402 0.0000
San Fernando 403 0.0000
Upper Gorge 407 0.0000
Exchequer 409 0.0000
McSwain 410 0.0000
Chicago Park 412 0.0000
Dutch Flat 2 413 0.0000
Beardsley 414 0.0000
Donnells 415 0.0000
Tulloch 416 0.0000
Forbestown 417 0.0000
Kelly Ridge 418 0.0000
Woodleaf 419 0.0000
French Meadows 424 0.0000
Middle Fork 425 0.0000
Oxbow (CA) 426 0.0000
Ralston 427 0.0000
Parker 428 0.0000
Camino 430 0.0000
Jaybird 431 0.0000
Loon Lake 432 0.0000
Robbs Peak 433 0.0000
White Rock/Slab Creek 435 0.0000
Devil Canyon 436 0.0000
Edward C Hyatt 437 0.0000
Thermalito 438 0.0000
Don Pedro 439 0.0000
La Grange 440 0.0000
43 of 559

Version: April 2024
Folsom 441 0.0000
Judge F Carr 442 0.0000
Keswick 443 0.0000
Nimbus 444 0.0000
Shasta 445 0.0000
ONeill 446 0.0000
W R Gianelli 448 0.0000
Spring Creek 450 0.0000
Trinity 451 0.0000
Colgate 454 0.0000
Narrows 2 455 0.0000
Bear Valley 457 0.0000
Boulder Canyon Hydro 466 0.0000
Cabin Creek 467 0.0000
Georgetown Hydro 472 0.0000
Salida 474 0.0000
Shoshone (CO) 476 0.0000
Temescal 479 0.0000
Corona 480 0.0000
Perris 481 0.0000
Rio Hondo 482 0.0000
Coyote Creek 483 0.0000
Red Mountain 484 0.0000
Valley View 487 0.0000
Upper Dawson 489 0.0000
Manitou Springs 494 0.0000
Ruxton Park 495 0.0000
Boysen 505 0.0000
Lamar Plant 508 0.0000
Blue Mesa 512 0.0000
Estes 513 0.0000
Morrow Point 514 0.0000
Big Thompson 515 0.0000
Green Mountain 516 0.0000
Marys Lake 517 0.0000
Flatiron 518 0.0000
Pole Hill 519 0.0000
Lower Molina 520 0.0000
Upper Molina 521 0.0000
Camp Far West 531 0.0000
Jones Fork 534 0.0000
Camanche 537 0.0000
Navajo Dam 584 0.0000
Drop 1 585 0.0000
East Highline 586 0.0000
44 of 559

Version: April 2024
South Fork Tolt 622 0.0000
Oak Flat 626 0.0000
Newcastle 632 0.0000
Kerckhoff 2 682 0.0000
Medicine Bow 692 0.0000
Toadtown 714 0.0000
Etiwanda 745 0.0000
Moccasin Low Head Hydro Project 751 0.0000
Sly Creek 776 0.0000
Gem State 790 0.0000
American Falls 809 0.0000
Bliss 810 0.0000
Cascade Dam 813 0.0000
Clear Lake 814 0.0000
Lower Malad 815 0.0000
Lower Salmon 816 0.0000
Shoshone Falls 818 0.0000
Swan Falls 819 0.0000
Thousand Springs 820 0.0000
Twin Falls (ID) 821 0.0000
Upper Salmon A 822 0.0000
Upper Malad 823 0.0000
Ashton 825 0.0000
Grace 827 0.0000
Oneida 829 0.0000
Soda 831 0.0000
Scott Flat 839 0.0000
City Power Plant 841 0.0000
Lower No 2 843 0.0000
Upper Power Plant 844 0.0000
Combie South 846 0.0000
Alamo 905 0.0000
Quincy Chute 917 0.0000
Hydro Plant No 3 925 0.0000
Last Chance 987 0.0000
Manti Lower 1020 0.0000
Black Eagle 2181 0.0000
Cochrane 2182 0.0000
Hauser 2185 0.0000
Morony 2191 0.0000
Mystic 2192 0.0000
Rainbow (MT) 2193 0.0000
Ryan 2194 0.0000
Thompson Falls 2195 0.0000
Yellowtail 2204 0.0000
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Version: April 2024
Clearwater 1 3020 0.0000
Clearwater 2 3021 0.0000
Eagle Point 3024 0.0000
East Side 3025 0.0000
Fish Creek 3026 0.0000
John C Boyle 3028 0.0000
Lemolo 1 3029 0.0000
Prospect 1 3032 0.0000
Prospect 2 3033 0.0000
Prospect 3 3034 0.0000
Prospect 4 3035 0.0000
Slide Creek 3036 0.0000
Soda Springs 3037 0.0000
Toketee Falls 3040 0.0000
Wallowa Falls 3041 0.0000
Faraday 3045 0.0000
North Fork 3047 0.0000
River Mill 3049 0.0000
Round Butte 3050 0.0000
Sullivan 3053 0.0000
Carmen Smith 3067 0.0000
Walterville 3071 0.0000
Upper Beaver 3643 0.0000
Cutler Hydro 3646 0.0000
Granite 3651 0.0000
Pioneer 3656 0.0000
Snake Creek 3658 0.0000
Stairs 3659 0.0000
Weber 3661 0.0000
Brigham City 3666 0.0000
Hydro III 3675 0.0000
Manti Upper 3676 0.0000
Bartholomew 3688 0.0000
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Sky River Wind Energy Center 50536 0.0000
Bowman 50546 0.0000
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Lilliwaup Falls Generating 50700 0.0000
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Oak Creek Energy Systems I 50754 0.0000
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85 A 52162 0.0000
85 B 52163 0.0000
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Coram Energy LLC 54299 0.0000
CTV Power Purchase Contract Trust 54300 0.0000
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Weeks Falls 54387 0.0000
Dry Creek Project 54394 0.0000
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San Gorgonio Windplant WPP1993 54454 0.0000
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Horseshoe Bend Hydroelectric Co 54524 0.0000
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Collierville Powerhouse 54555 0.0000
Hazelton B Hydro 54558 0.0000
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Kekawaka Power House 54654 0.0000
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Coram Tehachapi 54750 0.0000
Lateral 10 Ventures 54753 0.0000
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Black Creek 54860 0.0000
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Green Power I 55396 0.0000
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Rock River I LLC 55740 0.0000
Ridge Crest Wind Partners 55741 0.0000
Boulder City Silver Lake Hydro 55931 0.0000
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Helzel & Schwarzhoff 86 56275 0.0000
ZCO 56276 0.0000
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Judith Gap Wind Energy Center 56377 0.0000
Nevada Solar One 56405 0.0000
Pine Tree Wind Power Project 56433 0.0000
Burley Butte Windpark 56434 0.0000
Golden Valley Wind Park LLC 56435 0.0000
Milner Dam Wind Park LLC 56437 0.0000
Oregon Trail Wind Park 56439 0.0000
Pilgrim Stage Wind Park 56440 0.0000
Salmon Falls Wind Park 56441 0.0000
Thousand Springs Wind Park 56442 0.0000
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Buena Vista Energy LLC 56446 0.0000
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Marengo Wind Plant 56466 0.0000
SunE Alamosa 56481 0.0000
Mora Drop Hydroelectric Project 56498 0.0000
Tiber Dam Hydroelectric Plant 56499 0.0000
Western 102 Power Plant 56500 0.0000
Nellis Air Force Base Solar Array 56568 0.0000
Terra-Gen VG Wind LLC 56570 0.0000
Horseshoe Bend Wind Park 56591 0.0000
Rancho Penasquitos 56615 0.0000
Mountain Home 56636 0.0000
Bennett Creek Windfarm LLC - Mountain Home 56637 0.0000 Hatchet Ridge Wind Project 56654 0.0000
Goodnoe Hills 56666 0.0000
Russell D Smith 56694 0.0000
Spanish Fork Wind Park 2 LLC 56751 0.0000
Mountain Wind Power LLC 56752 0.0000
Mountain Wind Power II LLC 56753 0.0000
CalRenew-1 56768 0.0000
Dillon Wind LLC 56791 0.0000
CSU Fresno Solar Project 56813 0.0000
Denver Int Airport 56815 0.0000
Glenrock 56841 0.0000
Rolling Hills 56842 0.0000
Seven Mile Hill 56843 0.0000
Wheat Field Wind Power Project 56854 0.0000
Bolthouse S&P and Rowen Farms Solar 56862 0.0000
Shiloh Wind Project 2 LLC 56874 0.0000
Chester Diversion Hydroelectric Project 56893 0.0000
Gap Pacific Distribution Center 56909 0.0000
Imperial Valley Solar, LLC 56917 0.0000
WWRF Solar Plant 56922 0.0000
Threemile Canyon 56933 0.0000
Cassia Wind 56934 0.0000
Cassia Gulch 56935 0.0000
Solar Blythe LLC 56939 0.0000
Happy Jack Windpower Project 56960 0.0000
Butter Creek Power LLC 56967 0.0000
Big Top LLC 56968 0.0000
Four Corners Windfarm LLC 56969 0.0000
Four Mile Canyon Windfarm LLC 56970 0.0000
Oregon Trail Windfarm LLC 56971 0.0000
Pacific Canyon Windfarm LLC 56972 0.0000
Sand Ranch Windfarm LLC 56973 0.0000
Wagon Trail LLC 56974 0.0000
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Ward Butte Windfarm LLC 56975 0.0000
Solar Photovoltaic Project #02 56996 0.0000
Arrowrock Hydroelectric Project 56997 0.0000
SunEdison Walgreens Moreno Valley 57004 0.0000
Mariani Packing Vacaville Solar 57005 0.0000
Walgreens Woodland Distribution Center 57006 0.0000
SunEdison Ironwood State Prison 57007 0.0000
SunEdison Procter & Gamble Oxnard 57008 0.0000
Kohls San Bernardino Solar Facility 57009 0.0000
SunEdison Anheuser Busch Fairfield 57010 0.0000
Chuckawalla Valley State Prison 57011 0.0000
SunEdison Walmart Apple Valley DC 57012 0.0000
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High Plains 57040 0.0000
Vaca Dixon Solar Station 57041 0.0000
NaturEner Glacier Wind Energy 2 57050 0.0000
Campbell Hill Windpower 57090 0.0000
Silver Sage Windpower 57091 0.0000
Casper Wind Farm 57093 0.0000
Dry Lake Wind LLC 57098 0.0000
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Camp Reed 57125 0.0000
Yahoo Creek 57126 0.0000
Tuana Springs 57136 0.0000
Eurus Combine Hills Turbine Ranch 2 57137 0.0000
RV CSU Power LLC 57141 0.0000
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Spring Valley Wind Project 57192 0.0000
FPL Energy Montezuma Winds LLC 57201 0.0000
CM48 57205 0.0000
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Solar Photovoltaic Project #05 57219 0.0000
Solar Photovoltaic Project #06 57220 0.0000
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Solar Photovoltaic Project #08 57222 0.0000
Solar Photovoltaic Project #09 57223 0.0000
Solar Photovoltaic Project #10 57224 0.0000
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Solar Photovoltaic Project #18 57232 0.0000
Solar Photovoltaic Project #23 57236 0.0000
Solar Photovoltaic Project #22 57237 0.0000
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Cimarron Solar Facility 57243 0.0000
Kit Carson Windpower 57244 0.0000
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Solar Photovoltaic Project #27 57246 0.0000
Solar Photovoltaic Project #28 57247 0.0000
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Texico Wind Ranch LP 57258 0.0000
Crescent Dunes Solar Energy 57275 0.0000
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Alpine Solar 57295 0.0000
Dunlap 57299 0.0000
Garnet Wind Energy Center 57302 0.0000
Adelanto Solar Project 57305 0.0000
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Maclay Solar Project 57308 0.0000
Pacific Cruise Ship Terminals Berth 93 57309 0.0000
1420 Coil Av #C 57310 0.0000
Metro Support Services Center Solar 57313 0.0000
Los Angeles Harbor College 57314 0.0000
San Luis Valley Solar Ranch 57317 0.0000
Poseidon Solar, LLC 57318 0.0000
Top of the World Windpower Project 57327 0.0000
Mojave Solar Project 57331 0.0000
Roadrunner Solar 57338 0.0000
Panoche Valley Solar Farm 57340 0.0000
Avenal Park 57359 0.0000
Sun City Project LLC 57360 0.0000
Sand Drag LLC 57361 0.0000
Siphon Drop Power Plant 57364 0.0000
Cogentrix of Alamosa 57368 0.0000
Questa Solar Facility 57369 0.0000
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Greater Sandhill I 57377 0.0000
AV Solar Ranch One 57378 0.0000
Poseidon Wind, LLC 57379 0.0000
UASTP I 57392 0.0000
Genesis Solar Energy Project 57394 0.0000
Yolo County Solar Project 57422 0.0000
Buffalo Ridge II LLC 57424 0.0000
Ryegrass Windfarm 57427 0.0000
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Mainline Windfarm 57429 0.0000
Desert Meadow Windfarm 57430 0.0000
Cold Springs Windfarm 57431 0.0000
Juniper Ridge Hydroelectric Project 57437 0.0000
California Valley Solar Ranch 57439 0.0000
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Silver State Solar Power North 57442 0.0000
Two Ponds Windfarm 57444 0.0000
Solar Borrego I 57455 0.0000
Mountain View IV 57459 0.0000
Manzana Wind LLC 57484 0.0000
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Stroud Solar Station 57497 0.0000
Five Points Solar Station 57498 0.0000
Westside Solar Station 57499 0.0000
FRV SI Transport Solar LP 57506 0.0000
RV CSU Power II LLC 57507 0.0000
Carson Solar I 57509 0.0000
Ocotillo Express LLC 57514 0.0000
Giffen 57521 0.0000
Cantua Solar Station 57522 0.0000
Huron Solar Station 57523 0.0000
Roger Road WWTP 57524 0.0000
Solar Photovoltaic Project #32 57534 0.0000
Solar Photovoltaic Project #33 57535 0.0000
Garland Canal Power Plant 57551 0.0000
AFA Solar Farm 57554 0.0000
La Senita 57556 0.0000
Sunset Reservoir North Basin 57559 0.0000
Albuquerque Solar Energy Center 57567 0.0000
Los Lunas Solar Energy Center 57571 0.0000
Deming Solar Energy Center 57575 0.0000
Las Vegas Solar Energy Center 57576 0.0000
Alamogordo Solar Energy Center 57577 0.0000
PaTu Wind Farm LLC 57578 0.0000
Robert O Schulz Solar Farm 57579 0.0000
Broadridge Cogen 57580 0.0000
Shiloh III Wind Project LLC 57586 0.0000
Hatch Solar Energy Center I, LLC 57591 0.0000
Teichert Materials-Teichert Vernalis 57594 0.0000
Rising Tree Wind Farm 57621 0.0000
Foundation ST 57626 0.0000
Vestas Towers America, Inc. 57643 0.0000
City & County of Denver at Denver Int'l 57645 0.0000
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Adobe Solar 57651 0.0000
Yamhill Solar LLC 57652 0.0000
Bakersfield College Solar 01 57655 0.0000
Temescal Canyon RV, LLC 57656 0.0000
Avra Valley Solar 57657 0.0000
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Macys Goodyear 57673 0.0000
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Staples La Mirada, CA 57683 0.0000
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Topaz Solar Farm 57695 0.0000
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Aerojet II 57698 0.0000
Vasco Winds 57700 0.0000
Montezuma Wind II 57701 0.0000
Catalina Solar LLC 57708 0.0000
North Palm Springs 4A 57722 0.0000
Shiloh IV Wind Project LLC 57725 0.0000
Lake Hodges Hydroelectric Facility 57729 0.0000
SPS1 Dollarhide 57736 0.0000
SPS2 Jal 57737 0.0000
SPS3 Lea 57738 0.0000
SPS4 Monument 57739 0.0000
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Gordon Butte Wind LLC 57748 0.0000
Sawtooth Wind Project 57749 0.0000
SMUD at Lawrence 57753 0.0000
Coastal Energy Project 57756 0.0000
Pacific Wind LLC 57757 0.0000
Power County Wind Park South 57760 0.0000
Power County Wind Park North 57761 0.0000
Youngs Creek Hydroelectric Project 57763 0.0000
Naval Air Weapons Station China Lake 57764 0.0000
Arizona Western College PV 57765 0.0000
Rockland Wind Farm 57766 0.0000
Palo Verde College 57773 0.0000
Windstar 1 57774 0.0000
Kingman 1 57775 0.0000
RE Dillard 1 LLC 57777 0.0000
RE Kammerer 1 LLC 57778 0.0000
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RE Dillard 2 LLC 57779 0.0000
RE Kammerer 2 LLC 57780 0.0000
RE Dillard 3 LLC 57781 0.0000
RE Kammerer 3 LLC 57782 0.0000
RE Bruceville 1 LLC 57783 0.0000
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RE McKenzie 1 LLC 57816 0.0000
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RE McKenzie 4 LLC 57819 0.0000
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Heliocentric 57831 0.0000
Mustang Hills LLC 57833 0.0000
Pinyon Pine I 57834 0.0000
Alta Wind VIII 57835 0.0000
L-8 Solar Project 57836 0.0000
Pinyon Pine II 57837 0.0000
ISH Solar Hospital SDMC 57840 0.0000
ISH Solar Hospital Downey 57841 0.0000
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Green Acres Solar Facility 2 57850 0.0000
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Univ of California San Diego Solar 57856 0.0000
Industry MetroLink PV 1 57860 0.0000
Castle Rock Vineyards 57870 0.0000
Baldock Solar Highway 57882 0.0000
Queen Creek Solar Farm 57883 0.0000
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Gates Solar Station 57892 0.0000
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Tule Wind LLC 57913 0.0000
FRB Solar Farm 57930 0.0000
Solar Star California II LLC 57933 0.0000
Walmart Casa Grande 57939 0.0000
Macho Springs Power I 57947 0.0000
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Desert Green Solar Farm LLC 57959 0.0000
Brookfield Tehachapi 1 57962 0.0000
Musselshell Wind Project 57963 0.0000
Musselshell Wind Project Two LLC 57965 0.0000
Butte College Main Campus Solar 57970 0.0000
Busch Ranch Wind Energy Farm 57980 0.0000
Meridian Vineyards 57982 0.0000
SunE EPE2 LLC 57985 0.0000
SunE EPE1 LLC 57986 0.0000
Desert Sunlight 300, LLC 57993 0.0000
Alpaugh North 58002 0.0000
Alpaugh 50 58003 0.0000
Salt Palace Solar Gen Plant 58006 0.0000
High Mesa 58019 0.0000
IKEA Tejon 345 58028 0.0000
Nickel 1 Solar Facility 58034 0.0000
Buckeye Union HS District 201 58037 0.0000
Axium Modesto Solar 58039 0.0000
Black Mountain Solar LLC 58042 0.0000
Irwindale Brew Yard, LLC 58056 0.0000
Imperial Valley Solar Company 1 LLC 58062 0.0000
SEPV 1 58073 0.0000
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Edwards Air Force Base 58076 0.0000
Intel Folsom 58086 0.0000
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Meadow Creek Project Company 58106 0.0000
Foundation Cemex Madison 58112 0.0000
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La Joya Del Sol 58118 0.0000
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RE Kansas South LLC 58148 0.0000
TA-High Desert LLC 58149 0.0000
Black Cap Solar Plant 58150 0.0000
North Sky River Energy LLC 58154 0.0000
CSUF Trigeneration 58169 0.0000
Crafton Hills College Solar Farm 58170 0.0000
Prairie Fire 58171 0.0000
RE Victor Phelan Solar One LLC 58202 0.0000
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Grassland 1&2 Solar Project 58217 0.0000
Spion Kop Wind Farm 58218 0.0000
Newberry Solar 1 LLC 58226 0.0000
SEPV9 Power Plant 58227 0.0000
Tahquitz High School 58232 0.0000
Wagner Wind LLC 58233 0.0000
SEPV 8 58234 0.0000
Kit Carson 58240 0.0000
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Pierce College 58248 0.0000
CBS Television City 58253 0.0000
Los Alamos PV Site 58256 0.0000
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Exeter Solar 58306 0.0000
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Gridley Main 58370 0.0000
Gridley Main Two 58371 0.0000
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Corcoran Solar 58374 0.0000
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Fargo Drop 58384 0.0000
Solar Star 1 58388 0.0000
Solar Star 2 58389 0.0000
Flint Creek Hydroelectric LLC 58392 0.0000
Alta Wind X 58394 0.0000
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Heber Solar 58398 0.0000
Lone Valley Solar Park I LLC 58417 0.0000
Victor Dry Farm Ranch A 58418 0.0000
Victor Dry Farm Ranch B 58419 0.0000
CSU Northridge Plant 58422 0.0000
Centinela Solar Energy 58430 0.0000
Swauk Wind LLC 58441 0.0000
Arrache 4006 58445 0.0000
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Arrache 8083 58447 0.0000
Nunn 58448 0.0000
Rutan 58449 0.0000
Vinam 58450 0.0000
Ma 58451 0.0000
Horn 58452 0.0000
Watts 3115 58454 0.0000
45 Mile Hydroelectric Project 58455 0.0000
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Campo Verde Solar 58467 0.0000
C-Drop Hydro 58470 0.0000
Las Vegas WPCF Solar Plant 58477 0.0000
SEV NM Phase 2 58479 0.0000
CSU Pueblo 58481 0.0000
Picture Rocks Solar, LLC 58486 0.0000
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Spectrum Solar PV Power Project 58490 0.0000
RE Rosamond One LLC 58498 0.0000
RE Rosamond Two LLC 58499 0.0000
RE Rio Grande Solar LLC 58500 0.0000
RE Columbia 3 LLC 58502 0.0000
Chuckawalla Solar 58506 0.0000
Bear Creek Solar 58508 0.0000
Vintner Solar 58509 0.0000
Kettleman Solar Project 58510 0.0000
Ironwood Solar LLC 58513 0.0000
Desert Hot Springs Solar 58514 0.0000
Union HS at Casa Grande 58516 0.0000
Vista Grande HS at Casa Grande 58517 0.0000
Otero Solar 58520 0.0000
Manzano Solar 58521 0.0000
Madera Community Hospital 58522 0.0000
City of Hayward WWTP 58525 0.0000
Crown Cooling Facility 58527 0.0000
Garnet Solar Generation Station I LLC 58528 0.0000
Lake Pleasant WTP 58539 0.0000
Silver City WWTP PV Project 58540 0.0000
Desert Sunlight 250, LLC 58542 0.0000
Gilbert Solar Facility I, LLC 58543 0.0000
Mountain View Solar 58544 0.0000
Community Solar 1 58545 0.0000
SMPA Solar 1 Community Solar 58547 0.0000
Huerfano River Wind 58548 0.0000
GSE NM1 58576 0.0000
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Sonora 1 58578 0.0000
Oltmans SCE at Champagne 58581 0.0000
Oltmans SCE at Jurupa 58582 0.0000
Sierra Nevada Brewing Co Hybrid 58585 0.0000
Sue Cleveland High School 58588 0.0000
Rio Rancho High School 58589 0.0000
Cascade Solar 58590 0.0000
Solar Gen 2 Solar Facility 58592 0.0000
Beryl Solar Plant 58598 0.0000
Cedar Valley Solar Plant 58599 0.0000
Buckhorn Solar Plant 58600 0.0000
Milford Flat Solar Plant 58601 0.0000
Laho Solar Plant 58602 0.0000
Greenville Solar Plant 58603 0.0000
Granite Peak Solar Plant 58604 0.0000
Industry Solar Power Generation Station 1 LLC 58609 0.0000 Navajo Solar Power Generation Station 1 LLC 58610 0.0000 Powhatan Solar Power Generation Station 1
LLC 58611 0.0000
Otoe Solar Power Generation Station 1 LLC 58612 0.0000
Westlands Solar PV Farm 58616 0.0000
Sol Orchard El Centro PV 58621 0.0000
Carter Hydro 58622 0.0000
Santa Rita Jail Hybrid 58625 0.0000
Western Antelope Blue Sky Ranch A 58626 0.0000
Western Antelope Dry Ranch 58627 0.0000
Actus Lend Lease DMAFB 58632 0.0000
Monterey Regional Water Pollution Control
Agency 58633 0.0000
Lancaster Baptist Church 58634 0.0000
Sacramento Fairbain Water Treatment Plant 58636 0.0000
Tulare 1 and 2 58642 0.0000
Stateline Solar 58646 0.0000
Utah Red Hills Renewable Energy Park 58660 0.0000
Blue Sky One 58689 0.0000
Nooksack Hydro 58696 0.0000
Mira Loma 58698 0.0000
Phoenix Airport East Economy Lot 58708 0.0000
Phoenix Airport Rental Car Center 58709 0.0000
Lost Hills/Blackwell 58711 0.0000
North Star Solar 58713 0.0000
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Orion Solar I 58718 0.0000
Orion Solar II 58721 0.0000
North Bay Solar 1 58748 0.0000
Lancaster Dry Farm Ranch B 58750 0.0000
Rodeo Solar C2 58751 0.0000
Rodeo Solar D2 58752 0.0000
Summer Solar A2 58753 0.0000
Summer Solar B2 58754 0.0000
Summer Solar C2 58755 0.0000
Summer Solar D2 58756 0.0000
Summer North Solar 58757 0.0000
Expressway Solar A 58761 0.0000
Expressway Solar B 58762 0.0000
Expressway Solar C2 58763 0.0000
Spring Canyon Expansion Wind Energy Ctr 58769 0.0000
South Canal Hydro-1 58783 0.0000
South Canal Hydro-3 58784 0.0000
Storrie Lake Solar Project 58794 0.0000
Shasta Solar Farm 58814 0.0000
Redcrest Solar Farm 58831 0.0000
Cogenra - TEP 58832 0.0000
Red Horse 2 58833 0.0000
Gato Montes Solar, LLC 58842 0.0000
ASTI 58889 0.0000
Beringer 58890 0.0000
Prosperity Energy Storage Facility Hybrid 58899 0.0000
Tri-County Water Hydropower Project 58901 0.0000
Valley Center 1 58906 0.0000
Valley Center 2 58907 0.0000
Ramona 1 58909 0.0000
Ramona 2 58911 0.0000
Santa Fe Springs Rooftop Solar BLDG M 58912 0.0000
Santa Fe Springs Rooftop Solar BLDG H 58913 0.0000
2081 Terzian Solar Project 58918 0.0000
2127 Harris Solar Project 58919 0.0000
2097 Helton Solar Project 58920 0.0000
Cloverdale Solar I 58949 0.0000
Intel Folsom Phase 2 58954 0.0000
Oregon University System OIT Klamath Falls 58961 0.0000 Las Virgenes Municipal Water District 58963 0.0000
Fairfield Wind 58966 0.0000
Fort Huachuca Solar PV Project 58972 0.0000
White River Solar 2 58973 0.0000
Henrietta Solar Project 58975 0.0000
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RE Camelot LLC 58983 0.0000
RE Adams East, LLC 58984 0.0000
RE Kansas Solar, LLC 58985 0.0000
RE Old River One, LLC 58986 0.0000
RE Columbia Two, LLC 58990 0.0000
RE Kent South, LLC 58991 0.0000
Two Dot Wind Farm 59003 0.0000
Woodmere Solar Farm 59008 0.0000
Hayworth Solar 59009 0.0000
Macho Springs 59010 0.0000
Rio Rico Solar 59044 0.0000
Vacaville 59058 0.0000
Chopin Wind LLC 59076 0.0000
Cottonwood Solar, LLC (Goose Lake) 59086 0.0000
Cottonwood Solar, LLC (City of Corcoran) 59087 0.0000
Calipatria Solar Farm 59088 0.0000
Division 1 59094 0.0000
Division 2 59095 0.0000
Division 3 59096 0.0000
Kettering Solar 1 59098 0.0000
Kettering Solar 2 59099 0.0000
Enerparc CA1 LLC 59122 0.0000
CSD 2- Freedom High 59129 0.0000
CSD 2 - Heritage High 59130 0.0000
Dartmouth Landfill 59131 0.0000
EAFB - North Base 59132 0.0000
EAFB - South Base 59133 0.0000
SDCCD - Miramar 59138 0.0000
SDCWA - Twin Oaks 59139 0.0000
Brighton PV Solar Plant 59144 0.0000
RE Mustang LLC 59150 0.0000
Lancaster Solar 1 59167 0.0000
Avalon Solar 59168 0.0000
Lancaster Solar 2 59169 0.0000
Hesperia 59182 0.0000
CID Solar, LLC 59183 0.0000
Sterling PV 3 59198 0.0000
Mesa PV1 59199 0.0000
Farmersville 59203 0.0000
Porterville 6 and 7 59219 0.0000
Rising Tree Wind Farm II 59235 0.0000
Rising Tree Wind Farm III 59236 0.0000
Lone Valley Solar Park II LLC 59237 0.0000
Eagle Springs Solar LLC 59239 0.0000
Rio Bravo Solar 1 LLC 59249 0.0000
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Rio Bravo Solar II LLC 59250 0.0000
Wildwood Solar II 59253 0.0000
Lancaster Little Rock 59262 0.0000
Merced Solar LLC 59265 0.0000
Mission Solar LLC 59267 0.0000
Hollister Solar LLC 59268 0.0000
Victor Mesa Linda B2 59269 0.0000
Victor Mesa Linda C2 59270 0.0000
Victor Mesa Linda D2 59271 0.0000
Victor Mesa Linda E2 59272 0.0000
SEPV Palmdale East 59273 0.0000
California PV Energy at ISD WWTP 59283 0.0000
Hanford 1 and 2 59300 0.0000
Beacon Solar Plant Site 5 59308 0.0000
Beacon Solar Plant Site 2 59309 0.0000
Hecate Energy Beacon Solar 1 59315 0.0000
Hecate Energy Beacon Solar 3 59316 0.0000
Hecate Energy Beacon Solar 4 59317 0.0000
Pumpjack Solar I 59322 0.0000
Sacramento (SMUD) 59323 0.0000
Golden Acorn Casino 59328 0.0000
City of Soledad Water Reclamation 59329 0.0000
Taylor Farms 59330 0.0000
Anheuser-Busch #2 59331 0.0000
Catalina Solar 2, LLC 59334 0.0000
Quinto Solar PV Project 59339 0.0000
Dorena Hydro-Electric Facility 59357 0.0000
SCE-Snowline-Duncan Road (North) 59359 0.0000
SCE-Snowline-Duncan Road (South) 59360 0.0000
Old Mill Solar 59374 0.0000
Wildwood Solar I, LLC 59380 0.0000
Enterprise Solar, LLC 59386 0.0000
Escalante Solar I, LLC 59387 0.0000
Escalante Solar II, LLC 59388 0.0000
Escalante Solar III, LLC 59389 0.0000
City of Tulare Water Facility 59395 0.0000
Searchlight Solar 59404 0.0000
Diamond Valley Solar Project 59405 0.0000
Newman Solar 59407 0.0000
Shafter Solar LLC 59408 0.0000
Madelyn Solar, LLC 59409 0.0000
Rudy Solar, LLC 59410 0.0000
Mitchell Solar, LLC 59411 0.0000
Algonquin SKIC20 Solar LLC 59412 0.0000
Corcoran Solar 2 59413 0.0000
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Atwell Island West Solar 59414 0.0000
Anaheim Solar Energy Plant 59416 0.0000
SCE-Snowline-White Road (South) 59421 0.0000
SCE-Snowline-White Road (North) 59422 0.0000
SCE-Snowline-White Rd (Central) 59423 0.0000
Baker Creek Hydroelectric 59428 0.0000
Solar Las Vegas MB-1 59430 0.0000
Sierra Solar Greenworks 59431 0.0000
Adelanto Solar II, LLC 59440 0.0000
Adelanto Solar, LLC 59441 0.0000
TA-Acacia, LLC 59443 0.0000
Valencia Solar 59454 0.0000
Tech Park Solar 59455 0.0000
Denver Intl Airport IV Solar 59462 0.0000
Alamo Solar 59469 0.0000
Ft. Churchill PV 59472 0.0000
Apple Campus 2 PV 59473 0.0000
Jett Creek Windfarm (Burnt River) 59490 0.0000
Benson Creek Windfarm (Burnt River) 59491 0.0000
Durbin Creek Windfarm (Burnt River) 59492 0.0000
Prospector Windfarm (Burnt River) 59493 0.0000
Willow Spring Windfarm (Burnt River) 59494 0.0000
Giffen Solar Park 59522 0.0000
Five Points Solar Park 59523 0.0000
Blackwell Solar Park 59524 0.0000
Wright Solar Park 59525 0.0000
Solar Oasis LLC 59528 0.0000
Borden Solar Farm 59531 0.0000
Springbok Solar Farm 1 59532 0.0000
Coronus Adelanto West 1 59536 0.0000
Coronus Adelanto West 2 59537 0.0000
Park Meridian #1 59539 0.0000
Rancho Cucamonga Dist #1 59540 0.0000
Terra Francesco 59541 0.0000
Putah Creek Solar Farm 59550 0.0000
Vega Solar 59555 0.0000
Sandoval Solar Energy Center 59558 0.0000
Springer Solar 1 59560 0.0000
Colton Solar One, LLC 59597 0.0000
Colton Solar Two, LLC 59598 0.0000
Tropico Solar PV Plant 59599 0.0000
Nicolis Solar PV Plant 59600 0.0000
Maricopa West Solar PV, LLC 59607 0.0000
AP North Lake I, LP 59610 0.0000
Meadow Lake Solar Energy Center 59618 0.0000
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Cibola 59619 0.0000
South Milford Solar Plant 59620 0.0000
Kettleman Solar -Centaurus 59633 0.0000
Sandstone Solar 59634 0.0000
Coronal Lost Hills 59638 0.0000
Forever 21 Retail, Inc. 59651 0.0000
Nordhoff Place 59652 0.0000
City of Truth or Consequences PV 59653 0.0000
Comanche Solar 59656 0.0000
Imperial Valley Solar Co (IVSC) 2, LLC 59657 0.0000
Sun Harvest Solar NDP1 59687 0.0000
Mt. Home Solar 1, LLC 59695 0.0000
Pavant Solar, LLC 59702 0.0000
Cottonwood Solar, LLC Cottonwood Carport 59703 0.0000
Seville 1 59722 0.0000
Seville 2 59723 0.0000
SEPV 18 59730 0.0000
Aspiration G 59737 0.0000
Citizen B 59738 0.0000
Lancaster WAD B 59739 0.0000
SEPV Mojave West 59740 0.0000
Sunnyside Ranch Community Solar Array 59742 0.0000
DSH (CA) - Coalinga State Hospital 59746 0.0000
River Mountains Solar 59747 0.0000
CDCR (CA) - Pleasant Valley State Prison 59748 0.0000
Pryor Mountain Wind 59757 0.0000
Davis Monthan AFB (AZ) West Airfield 59779 0.0000
Fiddler's Canyon #2 59786 0.0000
Fiddler's Canyon #1 59787 0.0000
Oregon University System Rabbit Field 59790 0.0000
Colon PV 59798 0.0000
Airport 1 Solar (DIA) 59807 0.0000
Tooele Army Depot(CSG) 59817 0.0000
Mohave Electric at Fort Mohave 59819 0.0000
Playa Solar 1, LLC 59827 0.0000
Springbok Solar Farm 2 59840 0.0000
Pikes Peak Solar Garden 1 LLC CSG 59848 0.0000
Adams Community Solar Garden LLC 59849 0.0000
Adams Community Solar Garden III LLC 59850 0.0000
Kingbird A Solar LLC 59868 0.0000
Little Bear Solar 1, LLC 59870 0.0000
UC Davis South Campus 59872 0.0000
Windhub Solar A LLC 59878 0.0000
North Rosamond Solar LLC 59879 0.0000
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Corcoran Solar 3 59900 0.0000
Oro Loma 59915 0.0000
SunE- E Philadelphia Ontario 59916 0.0000
Nellis Solar PV II 59919 0.0000
Fiddler's Canyon 3 59932 0.0000
RE Tranquillity 59939 0.0000
Great Valley Solar Portfolio Holdings, LLC 59940 0.0000 Iron Springs Solar, LLC 59941 0.0000
Morgan Lancaster 1 59942 0.0000
Granite Mountain Solar West, LLC 59945 0.0000
Granite Mountain Solar East, LLC 59946 0.0000
Bakersfield 111 59948 0.0000
Milford 2 59958 0.0000
Western Antelope Blue Sky B 59961 0.0000
North Lancaster Ranch 59962 0.0000
Central Antelope Dry Ranch C 59963 0.0000
Elevation Solar C 59964 0.0000
Latigo Wind Park 59965 0.0000
Golden West Power Partners LLC 59974 0.0000
Carousel Wind Farm LLC 59975 0.0000
RE Astoria 59976 0.0000
RE Astoria 2 59977 0.0000
Adapture CA2, LLC 59978 0.0000
Columbia Solar Energy, LLC 59979 0.0000
Morelos del Sol 60007 0.0000
Hooper Solar 60008 0.0000
SR Jenkins Ft Lupton 60023 0.0000
Little Rock Pham Solar 60026 0.0000
Adera Solar 60027 0.0000
SunE Rochester 60032 0.0000
CA Flats Solar 130, LLC 60033 0.0000
CA Flats Solar 150, LLC 60034 0.0000
Tequesquite Landfill Solar PV Project 60035 0.0000
Frontier Solar LLC 60039 0.0000
Cuyama Solar, LLC 60043 0.0000
Golden Hills Wind 60049 0.0000
Steel Bridge Solar, LLC 60057 0.0000
Lindberg FIeld Solar 60060 0.0000
Avalon Solar II 60062 0.0000
CED Avenal 60077 0.0000
CED Ducor 1 60078 0.0000
CED Ducor 2 60079 0.0000
CED Ducor 3 60080 0.0000
CED Ducor 4 60081 0.0000
Fresno Solar 60083 0.0000
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AVS Lancaster 1 60085 0.0000
US-TOPCO (Soccer Center) 60086 0.0000
Kingbird B Solar, LLC 60091 0.0000
Blythe Solar II, LLC 60092 0.0000
Blythe Solar 110, LLC 60093 0.0000
Blythe Solar III, LLC Hybrid 60094 0.0000
Blythe Solar IV, LLC 60095 0.0000
Oregon Convention Center 60112 0.0000
Granby Hydro 60119 0.0000
Lemoore 1 60142 0.0000
Peak View Wind Farm 60143 0.0000
Building F 60151 0.0000
Building G 60153 0.0000
Buidling L 60154 0.0000
Dulles 60182 0.0000
Freeway Springs 60183 0.0000
Solverde 1 60185 0.0000
Antelope DSR 1 60186 0.0000
Antelope DSR 2 60187 0.0000
Whitethorn Solar LLC 60193 0.0000
South Valley Solar Energy Center 60195 0.0000
Santa Fe Solar Energy Center 60196 0.0000
Santolina Solar Energy Center 60197 0.0000
Rio Communities Solar Energy Center 60198 0.0000
Strata Roof 1 60219 0.0000
Rancho Seco Solar, LLC 60226 0.0000
Estrella Mountain PV 60230 0.0000
Genentech-Oceanside Hybrid 60231 0.0000
RE Garland 60233 0.0000
Midway Solar Farm II 60237 0.0000
Algonquin SKIC 10 Solar, LLC 60242 0.0000
Valley View Solar 60247 0.0000
Skylark 60248 0.0000
Weymouth Solar Plant 60255 0.0000
Alta Luna 60258 0.0000
Pioneer Wind Park, LLC 60259 0.0000
Playa Solar 2 60261 0.0000
Westside Solar Power PV1 60275 0.0000
Castor Solar 60277 0.0000
Antelope Big Sky Ranch 60279 0.0000
Summer Solar LLC 60280 0.0000
Central Antelope Dry Ranch B LLC 60281 0.0000
SR Mavericks 60283 0.0000
Red Horse III 60285 0.0000
Montana Solar Facility 60300 0.0000
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Holloman Solar Facility 60301 0.0000
San Isabel Solar, LLC 60304 0.0000
Mesquite Solar 3, LLC 60308 0.0000
Portal Ridge Solar B, LLC 60310 0.0000
Portal Ridge Solar C, LLC 60311 0.0000
Midway Solar Farm III 60315 0.0000
Jeffco Community Solar Gardens LLC 60320 0.0000
Willow Spring Solar, LLC 60324 0.0000
Grove Solar Center, LLC 60330 0.0000
Hyline Solar Center, LLC 60331 0.0000
Open Range Solar Center, LLC 60332 0.0000
Railroad Solar Center, LLC 60333 0.0000
Thunderegg Solar Center, LLC 60334 0.0000
Vale Air Solar Center, LLC 60335 0.0000
Midway Solar Farm 1 60336 0.0000
Wal-Mart Truth or Consequences PV 60341 0.0000
Solar Las Vegas MB 2, LLC 60350 0.0000
Bison Solar LLC 60351 0.0000
Boulder Solar Power, LLC 60352 0.0000
Sulphur Springs 60381 0.0000
RE Garland A 60386 0.0000
RE Barren Ridge 1 60389 0.0000
Munro Valley Solar 60412 0.0000
Bonnybrooke PV 60413 0.0000
Calligan Creek Hydroelectric Project 60418 0.0000
RCWD PV Project 60426 0.0000
CA Dept of Public Health at Richmond 60428 0.0000
Three Peaks Power 60432 0.0000
E&B Resources 60446 0.0000
Pavant Solar II LLC 60449 0.0000
Corcoran 60450 0.0000
Bayshore Solar B, LLC 60474 0.0000
Bayshore Solar C, LLC 60475 0.0000
Bayshore Solar A, LLC 60481 0.0000
Longboat Solar, LLC 60485 0.0000
Greenfield Wind - MT 60486 0.0000
Redwood 4 Solar Farm 60490 0.0000
Springbok 3 Solar Farm Hybrid 60491 0.0000
SR Skylark B 60497 0.0000
Valley Center 60509 0.0000
Clear Spring Ranch PV Project 60511 0.0000
NLP Granger 60516 0.0000
Hancock Creek Hydroelectric Project 60517 0.0000
NorWest Energy 2, LLC 60548 0.0000
Solar Blythe 2 60558 0.0000
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Golden Fields Solar I, LLC 60590 0.0000
Solar Star California, XLI, LLC 60591 0.0000
Voyager Wind I 60594 0.0000
Jacobson 5 MW Solar 60603 0.0000
BC Solar 60616 0.0000
Rush Creek Wind 60619 0.0000
San Joaquin Solar 60678 0.0000
Amphitheater High School Solar 60684 0.0000
Canyon Del Oro High School Solar 60685 0.0000
Weld 1 Community Solar Array 60720 0.0000
Logan 1 Community Solar Array 60722 0.0000
Conejos 1 Community Solar Array 60723 0.0000
Arapahoe 3 Community Solar Array 60724 0.0000
Xcel Adams 2 Community Solar Array 60725 0.0000
Xcel Adams 1 Community Solar Array 60726 0.0000
SEPV Imperial Dixieland West 60744 0.0000
SEPV Imperial Dixieland East 60745 0.0000
Victory Solar LLC 60764 0.0000
American Kings Solar, LLC 60777 0.0000
PVN Milliken, LLC 60790 0.0000
SunAnza 60791 0.0000
CEC Solar #1117, LLC 60801 0.0000
Cloverdale Solar Center 60813 0.0000
Weber State University - Davis Campus PV 60821 0.0000
Intel - Ocotillo Campus Solar 60822 0.0000
Valley Sanitary District WTP Solar 60824 0.0000
Colgreen North Shore Solar Farm 60825 0.0000
US GSA - Sacramento 60846 0.0000
Dept of General Services -FTB 60861 0.0000
Timothy Lake Powerhouse 60868 0.0000
Solar Star California, XLIV, LLC 60869 0.0000
Boulder Solar II, LLC 60885 0.0000
Pavant Solar III 60886 0.0000
Westmont 300B 60914 0.0000
Jacumba Solar Farm 60947 0.0000
Owens Valley Solar Project 11 60953 0.0000
Whitney Point Solar 60975 0.0000
OSLH, LLC 60976 0.0000
CSUF State College 60978 0.0000
CSUF Nutwood Solar 60979 0.0000
NextEra Westside PV 60981 0.0000
Lindberg Field Solar 2 60984 0.0000
Ramona Solar Energy 60995 0.0000
Iron Horse Battery Storage Hybrid 60996 0.0000
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SCDA Solar 1 61006 0.0000
Marin Clean Energy Solar One 61013 0.0000
Twin Buttes II Wind 61040 0.0000
Foundation CDCR LAC 61066 0.0000
Foundation Scheid Vineyards 61067 0.0000
Battle Mountain Solar Project 61098 0.0000
Pima Community College - East Campus 61104 0.0000
Manteca Land PV 61115 0.0000
Delano Land 1 61116 0.0000
Bakersfield PV 1 61117 0.0000
Bakersfield Industrial PV 1 61118 0.0000
Quichapa 1 61119 0.0000
Quichapa 2 61120 0.0000
Quichapa 3 61121 0.0000
Intel Folsom Phase 3 61152 0.0000
Big Timber Wind Farm 61155 0.0000
Columbus Solar Project 61165 0.0000
Shavano Falls Hydro 61189 0.0000
Shavano Falls Hydro Drop 4 61190 0.0000
Drop 5 61191 0.0000
IKEA Las Vegas 462 61193 0.0000
T0588 Phoenix - AZ 61199 0.0000
OR Solar 2, LLC 61200 0.0000
OR Solar 3, LLC 61201 0.0000
Mount Signal Solar Farm V 61202 0.0000
Sacramento Regional County Sanitation PV 61209 0.0000
Green Beanworks C PV 61215 0.0000
Green Beanworks D PV 61216 0.0000
Head of U Canal Hydro Project 61217 0.0000
Golden Hills North Wind Energy Center 61222 0.0000
Westmont 300A 61249 0.0000
USPS PV 61250 0.0000
Antelope Expansion 2 61264 0.0000
Antelope DSR 3 61265 0.0000
Kayenta Solar Project 61268 0.0000
Gray Hawk Solar 61272 0.0000
Bear Creek Solar Center 61281 0.0000
River Bend Solar, LLC 61289 0.0000
South Mills Solar, LLC 61290 0.0000
Green Meadow Solar, LLC 61291 0.0000
SR Kersey 61314 0.0000
Port of LA Solar FiT Project 61319 0.0000
Great Divide Solar, LLC 61335 0.0000
Black Eagle Solar, LLC 61336 0.0000
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Magpie Solar, LLC 61337 0.0000
Mill Creek Solar (OR) 61338 0.0000
Green Beanworks B PV 61339 0.0000
Westmont 400A 61348 0.0000
Westmont 400B 61349 0.0000
Mount Signal Solar Farm II 61353 0.0000
Sweetwater Solar 61369 0.0000
Amazon - Patterson PV 61377 0.0000
Valencia 1 Solar CA 61418 0.0000
One Ten Partners PV 61419 0.0000
Merced 1 PV 61420 0.0000
Madera 1 PV 61421 0.0000
OR Solar 5, LLC 61423 0.0000
OR Solar 8, LLC 61424 0.0000
Coyote Ridge Community Solar 61425 0.0000
OR Solar 6, LLC 61430 0.0000
Panasonic Carport Solar Hybrid 61439 0.0000
Foundation California Training Facility 61442 0.0000
Foundation Mann Packing 61443 0.0000
Foundation SaIinas Valley State Prison 61444 0.0000
Gaskell West 1 Solar Facility 61445 0.0000
SR Platte Solar Farm 61462 0.0000
Vandenberg Solar Project 61463 0.0000
San Luis Solar Garden 61472 0.0000
Adams Solar Center 61496 0.0000
Elbe Solar Center 61497 0.0000
Klamath Falls Solar 2 CSG 61553 0.0000
Facebook 1 Solar Energy Center 61556 0.0000
Facebook 2 Solar Energy Center 61557 0.0000
Facebook 3 Solar Energy Center 61558 0.0000
Woodline Solar 61559 0.0000
Eagle Point Solar 61560 0.0000
Denver Metro Solar 61563 0.0000
Tumbleweed Solar, LLC 61580 0.0000
Voyager Wind II 61582 0.0000
Voyager Wind III 61583 0.0000
Voyager Wind IV 61584 0.0000
Westmont 301 61593 0.0000
Westmont 401 61594 0.0000
San Luis Valley Solar Array 61605 0.0000
Vilas Solar Array 61606 0.0000
Stenner Creek Solar 61607 0.0000
Techren Solar I LLC 61611 0.0000
CDCR (CA) - Solano State Prison 61619 0.0000
CDCR (CA) - Corcoran State Prison 61620 0.0000
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CDCR (CA) - Wasco State Prison 61621 0.0000
Kilroy Solar 61628 0.0000
Chiloquin Solar, LLC 61631 0.0000
Carrizozo Solar 61662 0.0000
Pinal Central Energy Center Hybrid 61678 0.0000
USG 1 61682 0.0000
USG 2 61683 0.0000
North Gooding Main Hydro 61688 0.0000
IVC Solar 61692 0.0000
Folsom SP and CSP Sacramento 61698 0.0000
Aerolease 61718 0.0000
Wistaria Ranch Solar 61750 0.0000
Quincy II Solar Garden 61752 0.0000
Imboden Solar Garden 61753 0.0000
Stage Gulch Solar 61791 0.0000
Lavio Solar 61792 0.0000
EGP Stillwater Solar PV II, LLC 61809 0.0000
Titan Solar 61811 0.0000
RPUWD Scheuer Well Solar Project 61824 0.0000
Dignity - Siena Campus 61825 0.0000
Dayton Cutoff Solar 61827 0.0000
Valley Creek Solar 61828 0.0000
Silverton Solar 61829 0.0000
Sheep Solar 61830 0.0000
Colton Solar 61831 0.0000
Interstate Solar 61832 0.0000
Soboba Community Solar Project 61834 0.0000
Grand Ronde Solar 61835 0.0000
SeaWorld Aquatica 61843 0.0000
Brush Solar Center 61844 0.0000
Eagle Shadow Mountain Solar Farm 61852 0.0000
Jordanelle Dam Hydroelectric Project 61853 0.0000
Baker City Solar 61854 0.0000
Morgan Solar Center 61855 0.0000
Vale Solar Center 61856 0.0000
Stillwater Wind, LLC 61858 0.0000
Ontario Solar Center 61860 0.0000
Dignity - San Martin 61862 0.0000
Bar D 61886 0.0000
National Raisin 61894 0.0000
Casa Mesa Wind Energy Center Hybrid 61925 0.0000
Techren Solar II LLC 61930 0.0000
Techren Solar III LLC 61931 0.0000
Techren Solar IV LLC 61932 0.0000
Adams Nielson Solar 61933 0.0000
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Pacific Ethanol Madera Solar Array 61989 0.0000
Pioneer Solar (CO), LLC 61991 0.0000
UC Merced Solar Hybrid 61995 0.0000
San Pablo Raceway 62004 0.0000
Mustang Two 62015 0.0000
UC Riverside Lots 30 & 32 62016 0.0000
Stanford Campus Solar 62020 0.0000
CSU Long Beach Lots 7 & 14 62028 0.0000
Santa Rosa Junior College Petaluma Solar 62039 0.0000
Citizens Imperial Solar 62052 0.0000
Lancaster 62056 0.0000
Urtica Solar Project 62067 0.0000
Penstemon Solar Project 62069 0.0000
Camas Solar Project 62071 0.0000
Pima Community College 62075 0.0000
Blue Shld Of Cal- El Dorado Hlls Mtr B 62077 0.0000
Syncarpha Eagle Nest 62149 0.0000
Chaffey College Rancho Cucamonga Campus 62150 0.0000
Clif Bar Bakery of Twin Falls 62151 0.0000
Boring Solar LLC 62169 0.0000
Ballston Solar LLC 62170 0.0000
Labish Solar LLC 62171 0.0000
Desert Harvest, LLC 62177 0.0000
Maverick Solar, LLC 62178 0.0000
CNMEC Solar Energy Center 62191 0.0000
Oak Leaf Solar XXVII LLC 62224 0.0000
Oak Leaf Solar XXX LLC (CSG) 62239 0.0000
NorWest Energy 9 LLC 62241 0.0000
County of San Diego SBRC 62242 0.0000
Oak Leaf Solar XXI (CSG) 62243 0.0000
Oak Leaf Solar XXXI LLC (CSG) 62244 0.0000
Oak Leaf Solar XXV LLC (CSG) 62245 0.0000
Target Woodland Solar Project 62246 0.0000
Arrow Canyon Solar Hybrid 62248 0.0000
Oak Leaf Solar XXXII (CSG) 62251 0.0000
Oak Leaf Solar XXII LLC (CSG) 62252 0.0000
Oak Leaf Solar XXIV LLC (CSG) 62253 0.0000
Oak Leaf Solar XXVI LLC 62254 0.0000
Oak Leaf Solar XXVIII LLC (CSG) 62255 0.0000
Oak Leaf Solar XXIII LLC (CSG) 62256 0.0000
Trout Creek Solar 62260 0.0000
NorWest Energy 4, LLC 62268 0.0000
Bly Solar Center 62272 0.0000
Liberty HS Solar Project 62274 0.0000
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Frontier HS Solar Project 62275 0.0000
Xebec 1 62286 0.0000
Francisco St. Solar 62287 0.0000
Valentine Solar, LLC 62288 0.0000
Antelope Expansion 1B 62320 0.0000
Grazing Yak Solar 62376 0.0000
CFW Solar X LLC - Vaughn 62378 0.0000
Sage Solar I-III 62399 0.0000
City of Gallup Solar 62406 0.0000
Techren Solar V 62440 0.0000
Busch Ranch II Wind Farm 62445 0.0000
Little Bear 3 62463 0.0000
Little Bear 4 62464 0.0000
Little Bear 5 62465 0.0000
Vista Solar Energy Center 62467 0.0000
Cove Mountain Solar 62469 0.0000
Cove Mountain Solar 2 62470 0.0000
Crossing Trails Wind Power Project LLC. 62489 0.0000
Palmer Solar 62495 0.0000
TB Flats 62516 0.0000
Renew Solar ABC Sacramento LLC 62545 0.0000
Aquamarine 62547 0.0000
Airport Solar 62560 0.0000
Preferred Freezer San Leandro 62578 0.0000
Ekola Flats 62591 0.0000
Rio De Oro Solar Energy Center 62597 0.0000
PFMG Solar Grossmont Helix LLC 62611 0.0000
NVSS-II 62636 0.0000
AZ State University - Tempe Campus Solar 62643 0.0000
SFDK Solar 62649 0.0000
Foundation Dole Fresh Vegetables 62654 0.0000
HL Solar 62655 0.0000
Hunter Solar LLC (UT) 62656 0.0000
Gilcrest Solar 62663 0.0000
Quincy Solar 62664 0.0000
Sigurd Solar LLC 62666 0.0000
Lafayette Horizon Solar CSG LLC 62667 0.0000
Antelope Expansion 3A 62673 0.0000
Antelope Expansion 3B 62674 0.0000
American Canyon Solar 62687 0.0000
Malech Solar Farm 62688 0.0000
Hellyer Solar Farm 62689 0.0000
Guadalupe Solar Farm 62690 0.0000
Mesa CSG 2 Massicotte 62718 0.0000
Mesa CSG 1 Murdock 62719 0.0000
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Solar Star Palo Alto I, LLC 62732 0.0000
Wheatridge Hybrid 62745 0.0000
RC Energy AA LLC Solar Facility 62756 0.0000
Bloomington Solar I 62805 0.0000
Shelter Creek Condominiums Solar 62806 0.0000
Milford Solar 1 62812 0.0000
Mountain Breeze Wind, LLC 62840 0.0000
Amazon Denver DEN3 62877 0.0000
East Line Solar 62899 0.0000
Windsor Floating Solar 62902 0.0000
Orchard Windfarm 1, LLC 62935 0.0000
South Peak Wind 62939 0.0000
Cheyenne Ridge Wind Farm 62952 0.0000
Grossmont HS Solar Project 62987 0.0000
Wildflower Solar 1 62988 0.0000
Bluewater CDEC 1 62994 0.0000
Grants CDEC 2 62995 0.0000
SCCCD - Clovis Community College 63021 0.0000
Prineville Solar Energy LLC 63049 0.0000
Millican Solar Energy LLC 63050 0.0000
CalCity Solar 1 63054 0.0000
Clover Creek Solar Community Solar 63061 0.0000
SCCCD - Fresno Community College 63068 0.0000
Reedley Community College Solar 63074 0.0000
Eagle Creek 63078 0.0000
Harry Allen Solar Energy LLC 63080 0.0000
San Miguel I Solar Energy Center 63081 0.0000
San Miguel II Solar Energy Center 63082 0.0000
UC Santa Cruz Solar 63091 0.0000
Syncarpha Taos 63123 0.0000
Syncarpha El Rito 63124 0.0000
Syncarpha Questa 63125 0.0000
Drew Solar LLC 63127 0.0000
Roundhouse Wind Energy Project 63133 0.0000
Tom Sifers Solar 63163 0.0000
Whiskey Hill Solar 63164 0.0000
Rio Rancho Solar Energy Center 63184 0.0000
Bio-Rad 63189 0.0000
CID Solar (CA) 63204 0.0000
Rafael Solar 63206 0.0000
Case Creek Solar 63207 0.0000
Kale Patch Solar 63208 0.0000
O'Neill Creek Solar 63235 0.0000
Mtn. Solar 1 63276 0.0000
Mtn. Solar 2 63277 0.0000
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CO LI CSG 1 - Kamerra 63278 0.0000
Athos Solar Project 63300 0.0000
Garrett Solar 63301 0.0000
Alticor Inc - Solar Project 63303 0.0000
Duus Solar, LLC 63330 0.0000
Firwood Solar, LLC 63331 0.0000
Starvation 63344 0.0000
OE_AZ1 63349 0.0000
Medline Ind. Phase 2 Tracy 63361 0.0000
Niagara Bottling Stockton 63363 0.0000
Phelan Pinon Hills CSD Solar 63376 0.0000
Mtn. Solar 3 CSG 63379 0.0000
Castaic Lake Phase II 63385 0.0000
Rancho Seco Solar II, LLC 63387 0.0000
City of Rio Rancho WWTP 63391 0.0000
IOS II-LAX9 63414 0.0000
Sierra Pacific Industries (2042-RD) 63416 0.0000
DGS Wasco State Prison 63418 0.0000
DGS Central California Womens Facility 63419 0.0000
Fresno Bullard High School Hybrid 63420 0.0000
Fresno Hoover High School Hybrid 63421 0.0000
Fresno Sunnyside High School Hybrid 63422 0.0000
Corriedale Wind Energy 63436 0.0000
Sun Streams 2 63440 0.0000
Tickle Creek Solar 63442 0.0000
Thomas Creek Solar 63443 0.0000
RE-VFO LLC 63455 0.0000
St Louis Solar 63456 0.0000
Pika Solar 63462 0.0000
Brush Creek Solar 63464 0.0000
Minke Solar 63465 0.0000
Drift Creek Solar 63466 0.0000
Bighorn Solar 63467 0.0000
Saint Solar 63476 0.0000
Alcalde Solar Array 63477 0.0000
Point Wind 63482 0.0000
D'Arrigo Brothers - Phase 4 63486 0.0000
Wister Solar 63487 0.0000
PSREC/SIAD Solar 63493 0.0000
Oso Grande Wind Farm 63502 0.0000
Copper Mountain Solar 5, LLC 63504 0.0000
Lund Hill Solar 63509 0.0000
Walnut Unified School District Walnut HS
Hybrid 63510 0.0000
Moonlight Packing - Phase 2 63514 0.0000
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California City 63516 0.0000
Lafayette 2 - Internal Services Dept 63527 0.0000
Pima Community College NW 63531 0.0000
Amazon DEN2 Solar Project 63536 0.0000
Chevron - Lost Hills Hybrid 63545 0.0000
Mohave Electric Cooperative at Joy Lane 63554 0.0000
Britton Solar Energy Center 63579 0.0000
SR Kersey II 63586 0.0000
SR Skylark C 63587 0.0000
Lafayette 2 - MLK Jr. Hospital (MLK) 63623 0.0000
Pleasanton - Amador Valley High School 63630 0.0000
Fort Rock I 63636 0.0000
Dunn Road Solar 63642 0.0000
North Kern State Prison Phase II 63651 0.0000
Mt Hope Solar 63663 0.0000
Williams Acres Solar 63664 0.0000
River Valley Solar 63665 0.0000
Oak Leaf Solar XXXIII LLC (Lantz) 63681 0.0000
Butler Solar, LLC 63694 0.0000
Golden Hill Wind 63710 0.0000
Rawhide Prairie Solar Hybrid 63722 0.0000
Slate Hybrid 63727 0.0000
Taos Mesa Energy Facility Hybrid 63728 0.0000
Platteville Solar CSG, LLC 63753 0.0000
Kroger La Habra 63758 0.0000
Soscol Ferry Solar 63761 0.0000
Silveira Ranch Road Solar 63762 0.0000
Bighorn Solar 1 63770 0.0000
Suntex Solar, LLC 63778 0.0000
Rock Garden Solar, LLC 63779 0.0000
Alkali Solar, LLC 63795 0.0000
West Hines Solar I, LLC 63796 0.0000
Bronco Plains Wind, LLC 63803 0.0000
Golden Field Solar III, LLC 63859 0.0000
Encino Solar Energy Center 63860 0.0000
IBM Solar 63869 0.0000
Camp San Luis Obispo 63870 0.0000
Kern Valley SP 63875 0.0000
Turquoise Nevada, LLC 63906 0.0000
SulusSolar17 63908 0.0000
Dodge Flat 63913 0.0000
Cedar Springs I 63914 0.0000
Cedar Springs II 63915 0.0000
Cedar Springs III 63916 0.0000
Riley 63925 0.0000
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Fort Rock IV 63926 0.0000
Vacaville Hospital 63928 0.0000
Titan Solar 1 (CA) 63932 0.0000
Central 40 63940 0.0000
Oasis Alta 63941 0.0000
DGS Valley State Prison 63947 0.0000
Palmer Creek Solar, LLC 63956 0.0000
Day Hill Solar, LLC 63957 0.0000
SSD Marion 3, LLC 63958 0.0000
SSD Marion 5, LLC 63959 0.0000
SSD Marion 6, LLC 63960 0.0000
SSD Clackamas 1, LLC 63961 0.0000
SSD Clackamas 4, LLC 63962 0.0000
SSD Clackamas 7, LLC 63963 0.0000
SSD Marion 1, LLC 63964 0.0000
SulusSolar35 63969 0.0000
FTF-PackingShed 63993 0.0000
Firebaugh-CCS-PV-1 63994 0.0000
SulusSolar33 64006 0.0000
SulusSolar28 64007 0.0000
MilfordSolar OR 64008 0.0000
BristolSolar 64009 0.0000
Alden Solar CSG LLC 64021 0.0000
SulusSolar22 64022 0.0000
Monte Vista Solar 2 CSG, LLC 64024 0.0000
San Diego - EMDF at San Diego 64028 0.0000
Fremont CO 1, LLC 64031 0.0000
GreenparkSolar 64033 0.0000
SulusSolar25 64034 0.0000
SulusSolar29 64048 0.0000
San Diego - NCRC at Vista 64049 0.0000
Orchard Windfarm 2, LLC 64051 0.0000
Orchard Windfarm 3, LLC 64052 0.0000
Orchard Windfarm 4, LLC 64053 0.0000
Wonderful Orchards - New Columbia 64055 0.0000
Wheatridge 1 64057 0.0000
Route 66 Energy Center, LLC 64076 0.0000
Tesla Reno GigaFactory 64098 0.0000
Desert Harvest II LLC 64103 0.0000
Maverick Solar 4, LLC 64104 0.0000
Maverick Solar 6, LLC 64105 0.0000
Maverick Solar 7, LLC 64106 0.0000
James W. Broderick Hydropower Plant 64123 0.0000
Fish Springs 64148 0.0000
SR Rattlesnake 64152 0.0000
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Graphite Solar I 64186 0.0000
Horn Rapids Solar, Storage and Training 64198 0.0000
Jack's Solar Garden 64200 0.0000
Wonderful Orchards - Westside 64220 0.0000
Wonderful Orchards - Belridge 64221 0.0000
Las Virgenes 64264 0.0000
Rock Creek 2 CSG 64265 0.0000
Alamosa Solar South CSG 64266 0.0000
Valencia 2 64267 0.0000
ESCA-LL-COLTON, LLC 64270 0.0000
SE Athos II, LLC 64290 0.0000
Dissigno Healdsburg FPV, LLC 64308 0.0000
Coachella Hills Wind 64323 0.0000
Summit Winds 64326 0.0000
Two Dot Wind Broadview East LLC 64332 0.0000
Mtn Solar 6 LLC (CSG) 64352 0.0000
NSE Camber Solar PS11 LLC (CSG) 64353 0.0000
NSE Camber BH CSG 2, LLC 64355 0.0000
NSE Camber Solar PS13 LLC (CSG) 64356 0.0000
NSE Camber Solar PS6 LLC CSG 64357 0.0000
NSE Camber Solar PS5 LLC (CSG) 64358 0.0000
Pivot Solar 12 LLC(CSG) 64359 0.0000
Western Meadowlark Solar SCS NE 1, LLC 64365 0.0000
Tranquillity ID 64376 0.0000
Amazon TUS2 64384 0.0000
Gilcrest V CSG 64386 0.0000
TruStile Doors - Denver 64388 0.0000
Firestone Walker Brewery - Phase 1 64391 0.0000
EMWD - Perris Valley RWRF 64396 0.0000
EMWD - San Jacinto RWRF NEM 64397 0.0000
EMWD - Sun City RWRF 64398 0.0000
EMWD - San Jacinto RES BCT 64399 0.0000
CSU San Jose State University 64401 0.0000
El Dorado County 64402 0.0000
California State Univ at Channel Islands 64403 0.0000
Mesa Carport PV 64404 0.0000
EMWD - Moreno Valley RWRF 64406 0.0000
Big Bear 64418 0.0000
Wilmot Energy Center LLC 64426 0.0000
Vallecitos Water District 64438 0.0000
Valencia 3 64441 0.0000
Arlington Microgrid 64446 0.0000
Byron Highway Solar 64471 0.0000
Arlington Energy Center II 64481 0.0000
Department of Justice 64517 0.0000
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CA Institute for Women 64518 0.0000
Centinela State Prison 64519 0.0000
Calipatria State Prison 64521 0.0000
Atascadero State Hospital 64523 0.0000
SoCore Clovis 1 64524 0.0000
Arlington Energy Center III 64564 0.0000
Central Line Solar, LLC 64566 0.0000
Broadway 2 - UC Riverside 64579 0.0000
Broadway 2 - Tucson Phase II 64580 0.0000
Prologis L.P 64600 0.0000
County of San Diego COC Hybrid 64601 0.0000
MC6 Hydro Facility 64607 0.0000
SEPV Sierra 64611 0.0000
Hudson - High Desert Hybrid 64624 0.0000
Rabbitbrush Solar, LLC 64630 0.0000
Borderlands Wind, LLC 64638 0.0000
Pivot Solar 4 LLC (CSG) 64648 0.0000
Pivot Solar 1 LLC (CSG) 64649 0.0000
Pivot Solar 14 LLC (CSG) 64650 0.0000
Pivot Solar 2 LLC (CSG) 64651 0.0000
Pivot Solar 15 LLC (CSG) 64652 0.0000
Pivot Solar 7 LLC (CSG) 64653 0.0000
Pivot Solar 3 LLC (CSG) 64654 0.0000
Pivot Solar 8 LLC (CSG) 64655 0.0000
Lake Herman 64676 0.0000
Van der Hoek Solar Array/ Dairy 64687 0.0000
Dos Palos 64693 0.0000
El Dorado Solar, LLC 64700 0.0000
Amazon PSP1 64751 0.0000
Redwood Coast Airport Microgrid 64766 0.0000
Brightwood Solar, LLC 64830 0.0000
Oak Leaf Solar XVIII LLC 64831 0.0000
Catalina Express 64836 0.0000
Marina South 64837 0.0000
Prairie 64846 0.0000
Deer Creek 2 64861 0.0000
Panorama Wind, LLC 64872 0.0000
Edwards Sanborn E3 64877 0.0000
Edwards Sanborn E1A 64878 0.0000
Edwards Sanborn E2 64879 0.0000
Venture 1 - 1A CSG 64880 0.0000
NMSU Solar and Storage 64881 0.0000
Cuba 2.5ac, LLC 64903 0.0000
Luciana 64909 0.0000
Edwards Sanborn S3 64928 0.0000
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Edwards Sanborn S1 64929 0.0000
BigBeau Solar, LLC 64993 0.0000
Sacramento Point West Medical Offices 64994 0.0000
SSI West Riverside Landfill LLC 65002 0.0000
Sun Mountain Solar 1 65032 0.0000
Kings River Syphon 65033 0.0000
Blythe Mesa Solar II 65053 0.0000
Niyol Wind, LLC 65059 0.0000
Fremont CA AutoFactory 65072 0.0000
Pitkin County Solar 65084 0.0000
Foothill Sanitary Landfill - Solar Array 65089 0.0000
IGS KSBD 65091 0.0000
Jicarilla Solar 2 65103 0.0000
Fremont - Kato Rd 65131 0.0000
University of the Pacific 65132 0.0000
Five H Farms Solar Array 65168 0.0000
Van der Kooi Dairy Solary Array 65169 0.0000
Donaghy-Stockton 65177 0.0000
Mtn. Solar 4 (CSG) 65178 0.0000
CSP Los Angeles 65182 0.0000
Broadway 3 - Tucson Phase I 65185 0.0000
Broadway 3 - UC Merced 1 65186 0.0000
Broadway 3 - UCSB Lot 38 65187 0.0000
Broadway 4 - Target Shafter 65188 0.0000
West Village Solar - Array 1Community Solar 65189 0.0000 West Village Solar - Array 2 Community Solar 65190 0.0000 Red Prairie Solar 65228 0.0000
OK Produce Fresno Carport 65229 0.0000
Venture 2 - 1B 65235 0.0000
Venture 3 - 1C 65236 0.0000
Venture 4 - 1D 65237 0.0000
Chambers 4 - Eastvale LGB3 65238 0.0000
Chambers 4 - Redland LGB4 65251 0.0000
Chambers 4 - Riverside LGB6 65252 0.0000
Chambers 4 - Rialto LGB8 65253 0.0000
Chambers 4 - Sacramento SMF1 65254 0.0000
Chambers 4 - Eastvale DCA2 65255 0.0000
Chambers 4 - San Bernardino SNA7 65256 0.0000
Wonderful Huller & Shellling 65277 0.0000
Wonderful Lost Hills 65278 0.0000
8500 Balboa PV, LLC 65330 0.0000
Danell Bros Inc 65364 0.0000
Lincoln WWTF Hybrid 65382 0.0000
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Bodega Avenue Solar LLC 65383 0.0000
Rancho Cordova Medical Offices 65384 0.0000
Gilead Oceanside Solar Project 65408 0.0000
Gilead Foster City Solar Project 65409 0.0000
CA-Ventura Co CCD-Oxnard College Canopy 65447 0.0000
Laredo Detention Facility - Solar 2, 3 65464 0.0000
Sealed Air Madera Solar Project 65469 0.0000
Graniterock Quarry 65485 0.0000
Sierra Pacific Chinese Camp 65510 0.0000
Vasquez V CSG 65520 0.0000
CA - Fresno County - Juvenile Hall 65528 0.0000
Calibrant Bakersfield LLC 65564 0.0000
Google Moffett Park Solar Project 65568 0.0000
Gilead Sciences La Verne Rooftop Solar 65569 0.0000
Clearwater Wind I 65577 0.0000
Gilcrest Sun CSG 65609 0.0000
Orange Coast College PH2 Solar Project 65614 0.0000
BBARWA 65617 0.0000
Gunnison Solar 65618 0.0000
Niagara Bottling - Rialto 65652 0.0000
Edwards Sanborn E1B 65674 0.0000
Edwards Sanborn E4 65675 0.0000
Edwards Sanborn E5 65676 0.0000
Edwards Sanborn S4 65677 0.0000
POM Juice Solar 65706 0.0000
POM Beverage Solar 65707 0.0000
Schumann Wind Farm 65737 0.0000
Canal Energy S23, LLC 65740 0.0000
Carnes Creek Solar (CSG) 65745 0.0000
Cosper Creek Solar (CSG) 65746 0.0000
Fruitland Creek Solar (CSG) 65747 0.0000
Kaiser Creek Solar (CSG) 65748 0.0000
Sandy River Solar (CSG) 65750 0.0000
Sesqui-C Solar (CSG) 65751 0.0000
Dover Dairy 65766 0.0000
Ventura Solar 65770 0.0000
Jackpot Solar, LLC 65778 0.0000
Wonderful Nursery 65783 0.0000
20701 Plummer PV, LLC 65794 0.0000
Shasta College PH2 Solar Project 65940 0.0000
DG Fairhaven Power LLC 10052 1.1335
Revol Greens CA, LLC 61754 1.1304
Biomass One, L.P. 10869 1.6732
Magnesium Corp. of America 58191 0.6164
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North Valmy Station 8224 1.2108
Rio Bravo Generating Station 55039 0.6237
Chalk Cliff Limited 50003 0.4479
Sierra Pacific Burlington 56406 0.4313
Gila River Power Station - Block 1 59338 0.3842
Gila River Power Station - Block 2 60768 0.3866
Gila River Power Station - Block 3 59784 0.4144
Gila River Power Station - Block 4 55306 0.3913
Mesquite Generating Station - Block 1 58557 0.3949
Mesquite Generating Station - Block 2 55481 0.3879
Santa Cruz Energy LLC 57876 0.5965
Ameresco Johnson Canyon 58397 0.5473
Ameresco Butte County 57771 0.5607
Calpine - Gilroy Energy Center, LLC, Wolfskill
Peaker 55855 0.5538
Alameda 7450 0.8444
Lodi 7451 0.8657
G2 Energy Hay Rd 58320 0.5370
Heber Geothermal 54689 0.0702
Brea Generation, LLC 10648 1.1335
NOVE Power Plant 50831 1.2157
San Marcos Energy LLC 10386 1.1335
Second Imperial Geothermal 54111 0.0000
Shoreham 2518 1.5080
Mammoth G1 10480 0.0702
Mammoth G2 10481 0.0702
Coachella 6060 1.0106
Rockwood 7824 0.8445
McGinness Hills 3 61912 0.0702
Ormesa Geothermal 50762 0.0702
Monterey One Water 54951 0.2946
ABEC #2 dba West-Star Dairy 61501 0.6607
ABEC #3 dba Lakeview Dairy 61502 0.6290
ABEC #4 dba CE&S Dairy 61503 0.6423
Cold Canyon 1 58379 0.6214
Zero Waste Energy Development Co LLC 60220 0.5162
Verwey-Hanford Dairy Digester #2 62418 0.5626
Verwey-Hanford Dairy Digester #3 62419 0.6660
ABEC Bidart-Old River LLC 58699 0.6921
Blundell 299 0.0702
BYUI Central Energy Facility 59496 0.2354
Shute Creek Facility 56312 0.4087
Hayden 525 1.0038
Sunnyside Cogen Associates 50951 1.4097
General Chemical 54318 0.4248
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Tesoro SLC Cogeneration Plant 56509 0.6005
City of Palo Alto 57714 0.3962
Springs Generating Station 56144 0.7471
Roseville Power Plant #2 7452 0.9369
McClellan (CA) 535 0.6639
Gianera 7231 0.7864
MM Tulare Energy 55160 0.7130
Oxnard Wastewater Treatment Plant 50224 0.4368
Cal State Univ San Bernardino FC01 57544 0.2932
H. Gonzales 56039 0.7391
Bear Valley Power Plant 56346 1.0146
Ormesa II 54724 0.0702
Valero Wilmington Cogeneration Plant 63285 0.4498
Oregon State University 57653 0.2192
Walnut Power Plant 4256 2.9553
Lopez Canyon 57730 1.1335
SANTA MARIA II LFG POWER PLANT 57100 1.1335
Tulare BioMAT Fuel Cell 61846 0.5529
Still Water Power 64141 0.6056
Diamond H Dairy Power 64622 0.5259
Tajiguas Resource Recovery Project 63094 0.6194
Long Beach Trigen, LLC 64005 1.1335
Trona Solar III LLC 64914 0.0000
Sheep Creek Community Solar Farm 65970 0.0000
Bonanza Power Plant 7790 0.9514
Hardin Generator Project 55749 1.2722
Craig 6021 1.0180
Gunlock 7069 0.0000
Paris 830 0.0000
Sand Cove 3636 0.0000
Veyo 3635 0.0000
Viva Naughton 7050 0.0000
McClure 151 1.2164
Shaffer 59396 0.0000
Findlay Wind Farm 60015 0.0000
Cape Cod Air Force Station - 6 SWS 58661 0.0000
Little Bay 60495 0.0000
Washington White Post Solar LLC 58135 0.0000
Bluegrass Ridge 56555 0.0000
Heartland Community College 59776 0.0000
Normanskill Hydro Project 50123 0.0000
Echo Wind Park 58121 0.0000
Cummins, Inc 60453 0.0000
Ball Mountain Hydro 59040 0.0000
Gunsight Mountain Wind Energy LLC 56776 0.0000
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Bridgewater 2719 0.0000
Richland Solar Center 59874 0.0000
Lewiston 977 0.0000
Graeagle 3247 0.0000
Difwind Farms Ltd V 54685 0.0000
Terra-Gen 251 Wind LLC 52161 0.0000
Mojave 5 52144 0.0000
Windpark Unlimited 1 10027 0.0000
Windpark Unlimited 2 60321 0.0000
Lost Hills Solar LLC 58712 0.0000
Hamilton Branch 242 0.0000
Lime Saddle 255 0.0000
Foote Creek II 55608 0.0000
Foote Creek III 55609 0.0000
Difwind Farms Ltd I 54681 0.0000
Difwind Farms Ltd II 54682 0.0000
Altech III 50485 0.0000
Victory Garden Phase IV LLC 52160 0.0000
Borel 328 0.0000
Solar Photovoltaic Project #44 57540 0.0000
Tule River 289 0.0000
Windland 50386 0.0000
Inskip 248 0.0000
San Joaquin 3 277 0.0000
Animas 2465 0.0000
Leaburg 3068 0.0000
Drop 2 (WA) 6507 0.0000
Newhalem 9842 0.0000
Helzel & Schwarzhoff 88 Wind Farm 52165 0.0000
Swanmill Windfarm I 54650 0.0000
Kanaka 54653 0.0000
Foote Creek IV 55610 0.0000
Dutch Wind Energy 57301 0.0000
Flatirons Campus (FC) 57692 0.0000
DOE Golden NWTC Research Side Hybrid 57693 0.0000
DOE Golden NREL Main Campus 57694 0.0000
2555 E Olympic Bl 57871 0.0000
Eubank Landfill Solar Array 59393 0.0000
Desert Star Hybrid 62965 0.0000
Highline 7224 0.0000
Beacon BESS 1 61431 0.0000
Southern Owens Valley Solar Ranch 57304 0.0000
Van Norman Bypass Solar Project 57307 0.0000
LATTC South Campus Solar 57312 0.0000
Foothill Solar Project 59799 0.0000
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GE - Tehachapi 57566 0.0000
Grand Valley Project Power Plant 473 0.0000
ELACC Photovoltaic Power Facility 56814 0.0000
Occidental College Solar Project 57311 0.0000
Bellevue Solar Project 57372 0.0000
WSMR I 58010 0.0000
VA Sepulveda Ambulatory Care Center 58249 0.0000
Gavilan Community College Solar Project 61993 0.0000
Antioch Central Utility Plant 65404 0.0000
Desert Wind Farm, LLC 59968 0.0000
Cottage Street Solar Facility 58568 0.0000
Duke Building 98 59433 0.0000
Stone Drop 499 0.0000
Hell Hole Powerhouse 763 0.0000
Dillard 4 LLC 57806 0.0000
Rancho Seco Solar 529 0.0000
John H Kerr 3833 0.0000
Crane Valley Powerhouse 230 0.0000
MEBA 60496 0.0000
Gopher Creek Wind Farm 61417 0.0000
Sullivan County - Adult Care Solar 60817 0.0000
CNE at Cambridge MD 59842 0.0000
Georgia Power at Wadley GA 59843 0.0000
Munich Re Plaza 59844 0.0000
Cedar Creek 3255 0.0000
Kern Canyon 7911 0.0000
Roseville Solar 62114 0.0000
USPS FiT 1B - BP14-009B-7001 S Central 61251 0.0000
USPS FiT 2A - BP14-011A-7001 S Central 61252 0.0000
USPS FiT 2B - BP14-011B-7001 S Central 61253 0.0000
Ormat Nevada, Inc./ GEM 2 & 3 - Geothermal 54038 0.0702 Ormat Nevada, Inc./ GEM 2 & 3 - Geothermal 10763 0.0702 San Joaquin No. 1 278 0.0000
Lower Tule River 365 0.0000
Wintec Energy Ltd 50276 0.0000
Sacramento Soleil LLC 56875 0.0000
Solar Photovoltaic Project #12 57226 0.0000
Post Rock Wind Power Project, LLC 57678 0.0000
Merck - Upper Gwynedd Solar Array 61198 0.0000
Gloucester Solar 63031 0.0000
Ballenger Road Solar A 63759 0.0000
Berry Road Solar 64472 0.0000
20333 Normandie PV, LLC 65331 0.0000
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Abel Road Bioenergy 65517 3.3442
Putah Creek Solar Farm North 66088 0.0000
CD4 (Casa Diablo) 63490 0.0000
Windsor Solar 59171 0.0000
Mammoth G3 10479 0.0702
Chaparral Springs 64864 0.0000
Simplot Phosphates 54472 0.3962
Yellow Pine Solar 66357 0.0000
Victory Pass 65743 0.0000
Daggett 2 64851 0.0000
Daggett 3 64852 0.0000
Lockhart Solar PV 10444 0.0000
Lockhart Solar PV II 66699 0.0000
Oberon Solar Project 65734 0.0000
Red Mesa Solar Project 66404 0.0000
Arica Project 65744 0.0000
McFarland Solar A 66636 0.0000
Chaparral Solar, LLC. 64864 0.0000
Strauss Wind, LLC 62113 0.0000
Expressway Solar A 58761 0.0000
Expressway Solar B 58762 0.0000
Highlander Solar 1, LLC (formerly SEPV8) 58234 0.0000
Highlander Solar 2, LLC (formerly SEPV9) 58227 0.0000
Resurgence Solar II 66620 0.0000
Estrella Solar & Storage 66772 0.0000
Brady 55991 0.0702
Star Peak Geothermal Plant 65773 0.0702
Altwind 1 - Altwind 1 P1 0.0000
Altwind 2 - Altwind 2 P2 0.0000
Altwind 3 - Altwind 3 P3 0.0000
Desert Winds I - Desert Winds I P4 0.0000
Desert Winds II Pwr Purch Trst - Desert Winds II
Pwr Purch Trst P5 0.0000
Desert Winds III - Desert Winds III P6 0.0000
San Gorgonio Altwind - San Gorgonio Altwind P7 0.0000
San Gorgonio East - San Gorgonio East P8 0.0000
1122-11423 Vanowen - FITS1042 - 11423
Vanowen St P9 0.0000
1160-2645 La Cienega Ave - FITS1043 - 2645 LA
CIENEGA P10 0.0000
1254-10261 Glenoaks Blvd - FITS1039 - 10261
Glenoaks Blvd P11 0.0000
1425-12360 Foothill Blvd - FITS1041 - 12360
FOOTHILL BL P12 0.0000
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14539 Blythe Solar PV - FITS1011 - 14539
Blythe St P13 0.0000
21717 Nordhoff - FiTS1007 - 21717 Nordhoff St P14 0.0000 8011-658 Venice Blvd. - FITS 1044 658 Venice
Blvd P15 0.0000
Bathke Broadway Properties - FiTS1001 - 2515
S Broadway P16 0.0000
Capelin Distribution Center - FiTS1006 - 20000 S
Western Ave P17 0.0000
Cathay LA - Solar Project - FiTS1021 - 1501 N
Main P18 0.0000
Chatsmouth Solar Project 1 - FiTS1002 - 9640
Owensmouth P19 0.0000
DS2 Solar FiT Project - FiTS1089 - 1115-1129 S
Boyle Avenue P20 0.0000
DS3 Solar FiT Project - FiTS1090 - 1103-1109 S
Boyle Avenue P21 0.0000
Figueroa & Ave 61 Center - FiTS1028 - 6100
North Figueroa St P22 0.0000
FITS1017 - 11115 Laurel Canyon Blvd - FITS1017
- 11115 Laurel Canyon Blvd P23 0.0000
Harbor Regional Park Ground Mount Solar
Array - FITS1085 - 1581 West L Street P24 0.0000
KSI Solar Whiteman - FITS1019 - 10500 Airpark
Way P25 0.0000
LAX Logistic Industrial Center - FiTD1012 -
5343/5353 Imperial Hwy P26 0.0000
Layline Distribution Center - FiTS1003 - 1000 W
Francisco St P27 0.0000
Mastercraft 96.64kW Solar PV - FITS1020 -
7463 Varna P28 0.0000
M-C Investments 4558 Brazil - FITS1065-4558
Brazil P29 0.0000
North Figueroa & Ave. 58-59 Center - FITS1071-
5801 N. Figueroa P30 0.0000
Oxen Solar I - FiTD1019 - 11313 Oxnard St. P31 0.0000
Prairie Solar I - FiTS1025 - 20001 W Prairie P32 0.0000 Prairie Solar II - FiTS1026 - 19809 W Prairie P33 0.0000 Saf Keep Melrose - FITS1016 - 4996 Melrose
Ave P34 0.0000
Saf Keep San Fernando - FITS1008 - 2840 San
Fernando Rd P35 0.0000
Shri Ji Ram Solar FIT Project - FITS1047 - 1933
W 60TH ST P36 0.0000
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SOL #1235 LOS ANGELES - FITS1040 -
6005/6033 S CENTRAL AV P37 0.0000
Sunstarter Solar CXVI - FiTS1027 - 3650 E
Olympic Blvd P38 0.0000
Tangen Building - FITS1009 - 11205 S Broadway
Place P39 0.0000
Van Nuys Air - Hannah Solar - FiTD1011 - 7855
Hayvenhurst Ave P40 0.0000
Aeroplex - FITS1100 - 16143 Waterman Dr P41 0.0000
Aeroplex 2 - FITS1099 - 7943 -7949 Woodley
Ave P42 0.0000
Flight Building 1 - FITS1049 - 16665 16667
Arminta St P43 0.0000
Flight Building 6 - FITS1054 - 16543 16545
Arminta St P44 0.0000
Flight Building 7 - FITS1055 - 7901 7915 7929
Ruffner Ave P45 0.0000
Flight Building 8 - FITS1056 - 16638 Arminta St P46 0.0000 Flight Building 10 - FITS1058 - 16604 16608
Arminta St P47 0.0000
Van Nuys Air - 16620 Stagg St - FITS1048 -
16620 Stagg St P48 0.0000
Flight Building 2 P49 0.0000
Flight Building 3 - FITS1051 - 16637 16639
Arminta St P50 0.0000
Flight Building 4 - FITS1052 - 16625 Arminta St P51 0.0000 Flight Building 5 - FITS1053 - 16611 16615
Arminta St P52 0.0000
Foothill - FITS1087 - 7061 Foothill Blvd P53 0.0000
13207 Bradley Avenue - FITS1098 - 13207
Bradley Avenue P54 0.0000
Flight Building 11 - FITS1059 - 16554 16556
Arminta St P55 0.0000
Flight Building 12 - FITS1060 - 16540 16542
Arminta St P56 0.0000
Flight Building 13 - FITS1061 - 16508-16526
Arminta St P57 0.0000
Sun Valley 2 - FITS1101 - 11063 Pendleton Ave P58 0.0000 BJE Solar FiT Project II - FITS1083 - 12607
Sherman Way P59 0.0000
Flight Building 9 - FITS1057 - 16626 Arminta St P60 0.0000 91 of 559

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Valley Solar 1 - FITS1094 - 9340 9400 Penfield
Ave P61 0.0000
Valley Solar 5 - FITS1093 - 9330 Winnetka Ave
N P62 0.0000
Valley Solar 6 - FITS1095 - 19840 19860
Nordhoff Pl P63 0.0000
BJE Solar FiT Project - FITS1084 - 7230 Bellaire
Avenue P64 0.0000
WE Solar FiT Project - FITS1082 - 11308
Penrose St P65 0.0000
US Customhouse - BP 14-011G - 300 S Ferry St P66 0.0000 Berths 153 154-155 - BP14-009F - 804 S Pier A
St P67 0.0000
Ardagh Cannery Building 8 - BP14-011D 936 S
Barracuda St P68 0.0000
Napa FIT - FITS1073 - 16901-16915 Napa St P69 0.0000
Flight Building 14 - FITS1062 - 7861 Ruffner
Avenue 16710 Stagg St P70 0.0000
Woodman and Nordhoff Center - FITS1067 -
9011-9079 Woodman Ave P71 0.0000
De Soto - FITS1103 - 9401 De Soto Ave P72 0.0000
LA Convention Center Carport Solar P73 0.0000
Main St - General Service HQ - Bldg 13 Rooftop
Solar P74 0.0000
Metro Center - Parking Garage Rooftop Solar P75 0.0000
Owens Dry Lake Solar Demonstration - Owens
Lake Solar Demo P76 0.0000
Valley Generating Station - Admin Bldg Canopy
Solar P77 0.0000
Harbor Generating Station - HGS Warehouse
Solar P78 0.0000
Solar Rooftops Program - Group 1 P79 0.0000
Haiwee Power Plant - Haiwee Power Plant HAI1 P80 0.0000 Haiwee Power Plant - Haiwee Power Plant HAI2 P81 0.0000 AT&T Park Solar Arrays P82 0.0000
SF Service Center Solar Array 1 P83 0.0000
SF Service Center Solar Array 2 P84 0.0000
CHARCOAL RAVINE P85 0.0000
HAT CREEK HEREFORD RANCH P86 0.0000
JAMES B. PETER P87 0.0000
JAMES CRANE HYDRO P88 0.0000
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JOHN NEERHOUT JR. P89 0.0000
KINGS RIVER HYDRO CO. P90 0.0000
LOFTON RANCH P91 0.0000
ORANGE COVE IRRIGATION DIST. P92 0.0000
ROCK CREEK WATER DISTRICT P93 0.0000
SCHAADS HYDRO P94 0.0000
SWISS AMERICA P95 0.0000
2103 HILL PRISTINE SUN LLC P96 0.0000
2105 HART (Oroville Solar) P97 0.0000
2154 Foote (Oroville Solar) P98 0.0000
AMERICAN ENERGY, INC. (SAN LUIS BYPASS) P99 0.0000
AMERICAN ENERGY, INC. (WOLFSEN BYPASS ) P100 0.0000
APEX 646-460 P101 0.0000
BROWNS VALLEY IRRIGATION DISTRICT P102 0.0000
BUCKEYE HYDROELECTRIC PROJECT P103 0.0000
CALAVERAS PUBLIC UTILITY DISTRICT #1 P104 0.0000
CALAVERAS PUBLIC UTILITY DISTRICT #2 P105 0.0000
CALAVERAS PUBLIC UTILITY DISTRICT #3 P106 0.0000
DIGGER CREEK RANCH P107 0.0000
Goose Valley Hydro (SB32) P108 0.0000
GreenLight- Peacock Solar Project P109 0.0000
JACKSON VALLEY IRRIGATION DIST P110 0.0000
Lassen Station Hydro P111 0.0000
MADERA CANAL (1174 + 84) P112 0.0000
Madera Canal (1923) P113 0.0000
MADERA CANAL STATION 1302 P114 0.0000
Mathew's Dam Hydro P115 0.0000
MCFADDEN HYDROELECTRIC FACILITY P116 0.0000
Mill Sulphur Creek Project P117 0.0000
NEVADA IRRIGATION DISTRICT NORTH COMBIE P118 0.0000
PCWA – Lincoln Metering and Hydroelectric
Station P119 0.0000
Pristine Sun- 2192 Ramirez P120 0.0000
Pristine Sun Alvares 2041 P121 0.0000
Pristine Sun Buzzelle P122 0.0000
Pristine Sun Christensen P123 0.0000
Pristine Sun Cotton 2096 P124 0.0000
PRISTINE SUN FITZJARRELL P125 0.0000
Pristine Sun Jardine P126 0.0000
PRISTINE SUN JARVIS P127 0.0000
Pristine Sun Rogers P128 0.0000
Pristine Sun Scherz P129 0.0000
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Pristine Sun Smotherman P130 0.0000
Pristine Sun Stroing P131 0.0000
Termoelectrica de Mexicali (MEX) P132 0.3962
Salmon Creek Hydroelectric Project P133 0.0000
Townsite Solar P134 0.0000
SHAMROCK UTILITIES (CEDAR FLAT) P135 0.0000
SHAMROCK UTILITIES (CLOVER LEAF) P136 0.0000
SIERRA GREEN ENERGY P137 0.0000
SILVER SPRINGS P138 0.0000
Sirius Solar P139 0.0000
TUNNEL HILL HYDROELECTRIC PROJECT P140 0.0000
Twin Valley Hydro P141 0.0000
Water Wheel Ranch P142 0.0000
YUBA COUNTY WATER AGENCY (Mini Hydro) P143 0.0000
GRASSHOPPER FLAT P144 0.0000
Sutter's Mill P145 0.0000
Hayward Paul Luckey P146 0.0000
J Bar 9 Ranch, Inc. (LU) P147 0.0000
West Side P148 0.0000
Cape Scott Wind P149 0.0000
Dokie Wind P150 0.0000
Meikle Wind P151 0.0000
Moose Lake Wind P152 0.0000
Pennask Wind Farm P153 0.0000
Quality Wind P154 0.0000
FIT - McClellan Park P155 0.0000
Sutter's Landing Solar P156 0.0000
SMUD PV - Hedge Substation PV Plant (Hedge
units 1-4) P157 0.0000
Cal Expo P158 0.0000
Utility Operations Center P159 0.0000
Shinish Creek Wind Farm P160 0.0000
TerraGen Mojave Wind Farms, LLC - Morwind P161 0.0000
CITY OF WATSONVILLE P162 1.1335
BLAKE'S LANDING FARMS, INC. (Biogas) P163 1.1335
Clover Flat LFG P164 1.1335
OPEN SKY DAIRY DIGESTER #2 P165 1.1335
SAN LUIS OBISPO AD (aka HZIU Kompogas) P166 1.1335
VERWEY MADERA DAIRY DIGESTER 2 (NEW) P167 1.1335
ABEC Bidart-Stockdale LLC P168 1.1335
Still Water Power P169 1.1335
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Van Warmerdam Dairy Digester P170 1.1335
New Hope Diary Digester P171 1.1335
Van Steyn P172 1.1335
Fiscalini Farms P173 1.1335
1080 CHESTNUT CORP. P174 0.3962
AIRPORT CLUB P175 0.3962
ARDEN WOOD BENEVOLENT ASSOC. P176 0.3962
CITY OF WATSONVILLE P177 0.3962
GREATER VALLEJO RECREATION DISTRICT P178 0.3962
HAYWARD AREA REC & PARK DIST. P179 0.3962
NIHONMACHI TERRACE P180 0.3962
ORINDA SENIOR VILLAGE P181 0.3962
SATELLITE SENIOR HOMES P182 0.3962
UC Davis Medical Center P183 0.3962
Elk Grove Milling P184 0.3962
GFP Ethanol, LLC dba Calgren Renew Fuels
(Pixley Cogen Partners, LLC) P185 0.3962
Techni-Cast Corp P186 0.3962
Aligned Microgrid P187 0.8144
La Joya Wind P188 0.0000
PacifiCorp - MJRP (TWO) P190 0.0000
Red Cloud Wind P193 0.0000
La Rosita Power Project (MEX) P194 0.4214
MCAS Yuma Microgrid MCGX02 P195 0.8144
Stotz Southern Generation P197 0.3026
Energía Sierra Juárez Wind 2 (MEX) P198 0.0000
26-foot Drop Small Hydro P199 0.0000
Blackspring Ridge 1A Wind Project (CAN) P200 0.0000
Blackspring Ridge 1B Wind Project (CAN) P201 0.0000
Bridge River 1 Hydroelectric Generation Facility
(CAN) P202 0.0000
Bridge River 2 Hydroelectric Generation Facility
(CAN) P203 0.0000
Cheakamus Hydroelectric Generation Facility
(CAN) P204 0.0000
Energía Sierra Juárez Wind Farm (MEX) P205 0.0000
G.M. Shrum Hydroelectric Generation Facility
(CAN) P206 0.0000
Grand View 5 East P207 0.0000
Halkirk I Wind Project (CAN) P208 0.0000
Kootenay Canal Hydroelectric Generation
Facility (CAN) P209 0.0000
Mica Hydroelectric Generation Facility (CAN) P210 0.0000 95 of 559

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Peace Canyon Hydroelectric Generation Facility
(CAN) P211 0.0000
Revelstoke Hydroelectric Generation Facility
(CAN) P212 0.0000
Seven Mile Hydroelectric Generation Facility
(CAN) P213 0.0000
Utility Built Solar (LADWP) P214 0.0000
FIT Solar P215 0.0000
IP Malbec P216 0.0000
Geo Solar 1 - Clearlake P217 0.0000
Geo Solar 2- Middletown P218 0.0000
BART Antioch Station JB-94525154 P219 0.0000
BART Lafayette Station JB-94525155 P220 0.0000
BART Warm Springs Station JB-94512464 P221 0.0000
City of Rancho Cucamonga - City Hall P222 0.0000
City of Rancho Cucamonga - Animal Center
Shelter P223 0.0000
City of Rancho Cucamonga - Epicenter P224 0.0000
Penitencia Water Treatment Plant PV P225 0.0000
Santa Teresa Water Treatment Plant PV P226 0.0000
Sonoma Valley Treatment Plant PV P227 0.0000
275 Cambridge Ave. Parking Garage - 275
Cambridge Garage P228 0.0000
445 Bryant St. Parking Garage - 445 Bryant St.

Parking Garage P229 0.0000
475 Cambridge Ave. Parking Garage - 475
Cambridge Garage P230 0.0000
520 Webster St. Parking Garage - 520 Webster
St. Parking Garage P231 0.0000
Unitarian Universalist Church of Palo Alto -
UUCPA P232 0.0000
NR Grower Direct Nut P233 0.0000
NR Pohl and Holmes Inc P234 0.0000
Parking Structure (Main Office) - Turlock Solar
Photovoltaic Project P235 0.0000
Mega Hydro #1 (Clover Creek) P236 0.0000
Lois Lake Dam (Powell River Hydro) P237 0.0000
Coyote Springs I P238 0.3799
Hood Street Reservoir Project [Hydro] P239 0.0000
Two Fiets - Van Beek Brothers Dairy Digester P240 1.1335 Glendale Community College - Glen Solar 1 -
Solar Parking Roof P241 0.0000
Rooftop Solar - City of Pittsburg P242 0.0000
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Central Marin Sanitation Agency - CMSA
Renewable Energy Expansion P243 1.1335
Cost Plus Plaza P244 0.0000
DRES Quarry 1 P245 0.0000
DRES Quarry 2.4 - DRES Quarry 2.4 P246 0.0000
Fairfield Power Plant (Papazian) - Fairfield
Power Plant (Papazian) P247 0.0000
Freethy Industrial Park Unit #1 P248 0.0000
Freethy Industrial Park Unit #2 P249 0.0000
Marin Carport - Buck Institute P254 0.0000
San Rafael Airport P255 0.0000
San Rafael Airport II P256 0.0000
SWTC - Phase 2 - Small World Trading Co P257 0.0000
City of Moreno Valley - City Hall Solar Carport P258 0.0000 City of Colton - Gonzalez Community Center JB-
9232227-00 P259 0.0000
City of Colton - Arbor Terrace JB-9231899-00 P260 0.0000 Jenny Strand Solar Park P261 0.0000
Santa Clara-Tioga Canopy P262 0.0000
Ameresco Santa Clara P263 1.1335
City of Oceanside (San Francisco Peak Hydro) P264 0.0000 Olivenhain Municipal Water District P265 0.0000
SDG&E-owned PV system at Del Sur
Elementary School P266 0.0000
SDG&E-Owned PV System at Hunter Industries,
Inc P267 0.0000
SDG&E owned PV Facility at Pacific Station P268 0.0000
SDG&E- owned PV system at Sanford-burnham
Medical Research Institute I P269 0.0000
SDG&E-Owned PV System at the Towers at
Bressi Ranch P270 0.0000
SDG&E owned PV Facility at Wilco Investments P271 0.0000 SFO International Airport - SFO International
Airport A P272 0.0000
SFPUC Southeastern Plant - SFPUC
Southeastern Plant Solar P273 0.0000
North Point DPW Water Pollution Control
Facility - North Point - DPW P274 0.0000
Moscone Center - Moscone Esplanade A P275 0.0000
Moscone Center - Moscone Esplanade B P276 0.0000
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Moscone Center - Moscone South Lobby P277 0.0000
City Distribution Division - CDD P278 0.0000
Maxine Hall - Maxine Hall P279 0.0000
Chinatown Library - Chinatown Library P280 0.0000
Muni Woods Motor Coach Facility - Muni
Woods P281 0.0000
Chinatown Public Health - Chinatown Public
Health P282 0.0000
Alvarado Elementary School - Alvarado Solar P283 0.0000 San Francisco Public Utilities Commission - HQ -
525 Golden Gate - Headquarters P284 0.0000
Davies Symphony Hall - Davies Symphony Hall P285 0.0000 North Beach Library Solar - North Beach Library
Solar P286 0.0000
700 Pennsylvania Ave. - 700 Pennsylvania Ave. P287 0.0000 Downtown High School-SFUSD - Downtown HS-
San Francisco Unified School District P288 0.0000
Thurgood Marshall HS-San Francisco Unified
School - Thurgood Marshall High School-SFUSD P289 0.0000 San Francisco City Hall - San Francisco City Hall P290 0.0000 Cesar Chavez Elementary School SFUSD - Cesar
Chavez Elementary School SFUSD P291 0.0000
San Francisco Unified School District - Burton
High School P292 0.0000
San Francisco Unified School District - Starr King
Elementary School P293 0.0000
Valley Pumping Plant P294 0.0000
Burbank #3 Flare P295 1.1335
IKEA Solar P296 0.0000
Burbank 1 P297 0.0000
Burbank 2 P298 0.0000
Burbank 3 P299 0.0000
Burbank 4 P300 0.0000
Burbank 5 P301 0.0000
Dutch Energy P302 0.0000
Desert Winds II Pwr Purch Trst P303 0.0000
SunE Solar XVI Lessor, LLC - SunE - Pico Rivera P304 0.0000 Marinos Ventures LLC P305 0.0000
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Master Development - Corona, CA (1351
Railroad) - Master Development - Corona, CA
(1351 Railroad) P306 0.0000
San Dimas Technology and Development
Center - San Dimas Technology and
Development Center P307 0.0000
Caliente - II - Caliente - II P308 0.0000
Walnut Valley Water District - Walnut Valley
Water District P309 0.0000
Fulton Road - Three Valleys MWD (Fulton Road) P310 0.0000 Williams - Three Valleys MWD (Williams) P311 0.0000
Santa Rosa - Calleguas MWD - Unit 3 P312 0.0000
Snow Creek - Desert Water Agency (Snow
Creek) P313 0.0000
Goleta Water District - Goleta Water District P314 0.0000 City of Santa Barbara - Gibraltar Conduit
Hydroelectric Plant P315 0.0000
White Mountain Ranch LLC - White Mountain
Ranch LLC P316 0.0000
Conejo - Calleguas MWD - Unit 1 P317 0.0000
Monte Vista Water District - Monte Vista Water
District P318 0.0000
California Water Service Company - Palos
Verdes Station 37 P319 0.0000
Deep Springs College - Deep Springs College P320 0.0000 Camrosa County Water District - Camrosa
County Water District P321 0.0000
Unit 3 - Unit 3- San Bernardino MWD P322 0.0000
Bishop Tungsten Development, LLC - Pine Creek
Mill P323 0.0000
Hi Head Hydro Incorporated - Hi Head Hydro
Incorporated P324 0.0000
Desert Power Company - Desert Power
Company P325 0.0000
Palm - San Bernardino MWD P326 0.0000
Northwind - Wind Stream Operations, LLC -
Northwind - Wind Stream Operations, LLC P327 0.0000
One Miracle Property, LLC - One Miracle
Property, LLC P328 0.0000
Isabella Hydroelectric Project P329 0.0000
Desert Winds II Pwr Purch Trst P330 0.0000
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Cameron Ridge II P331 0.0000
Kirkwood Meadows Public Utility District
Powerhouse P332 0.8718
Anaheim Elementary School District - Betsy
Ross Elementary School P333 0.0000
Anaheim Elementary School District - Franklin
Elementary School P334 0.0000
Centralia School District - Centralia Elementary
School P335 0.0000
Centralia School District - Danbrook Elementary
School P336 0.0000
Magnolia School District - Dr. Jonas Salk
Elementary School P337 0.0000
Magnolia School District - Lord Baden-Powell
Elementary School P338 0.0000
Placentia Yorba Linda Unified School District -
Esperanza High School P339 0.0000
Savanna Unified School District - Cerritos
Elementary School P340 0.0000
Savanna Unified School District - Hansen
Elementary School P341 0.0000
Arbuckle Mountain Hydro, LLC. P342 0.0000
Cox Station Micro-Hydroelectric Project P343 0.0000
Southeast Health Center solar P344 0.0000
Alta Wind VII P345 0.0000
Alta Wind IX P346 0.0000
City of Santa Ana P347 0.0000
Lytle Creek P348 0.0000
Mill Creek No. 1 P349 0.0000
Ontario No. 1 P350 0.0000
Ontario No. 2 P351 0.0000
Sierra P352 0.0000
HDSI, LLC - Hudson High Desert Solar P353 0.0000
Garlock Energy, LLC - Garlock Energy, LLC P354 0.0000
IGS Valencia 3, LLC P355 0.0000
Lake Herman Solar P356 0.0000
Duran Mesa, LLC P357 0.0000
RE Slate 1 LLC – Bart Phase P358 0.0000
RE Slate 1 LLC – PWRPA Phase P359 0.0000
RE Slate 1 LLC – Stanford Phase P360 0.0000
RE Slate 1 LLC – CCCE Phase P361 0.0000
RE Slate 1 LLC – SVCE Phase P362 0.0000
Bodega Energy West P363 0.0000
Petaluma Energy East P364 0.0000
Redwood Coast Airport Microgrid P365 0.0000
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Point Wind 2 P366 0.0000
Cameron Ridge III P367 0.0000
Clines Corners Wind Farm P368 0.0000
Solar City - Gonzales Center (Dominion Solar) P369 0.0000 Solar City - Arbor Terrace (Dominion Solar) P370 0.0000 Pier 96 – Recycling Plant solar P371 0.0000
San Francisco Police Academy Solar Carport P372 0.0000
49 South Van Ness P373 0.0000
Visitacion Valley Middle School Solar PV P374 0.0000
Powell River Generation (Catalyst Paper) (CAN) P375 1.5704 Opera House solar P376 0.0000
Wister Solar P377 0.0000
City of Rancho Cucamonga - Fire Station 173 P378 0.0000 Alhambra Solar Facility - Alhambra Solar facility P379 0.0000 Arkansas Solar Facility - Arkansas Solar Facility P380 0.0000 Oakley RV & Boat Storage Phase 3 - Oakley RV
& Boat Storage Phase 3 P381 0.0000
Gansner Hydroelectric Project P382 0.0000
Gaskell West 3 P383 0.0000
Gaskell West 4 P384 0.0000
Gaskell West 5 P385 0.0000
Java Solar P386 0.0000
Chetwynd Biomass Power Plant P387 1.1335
Fraser Lake Bioenergy Plant P388 1.1335
Sukunka Wind Energy Project P389 0.0000
Zonnebeke Wind Project Limited Partnership P390 0.0000
St Anthony Hydro, LLC P391 0.0000
Byron Hot Springs Solar P392 0.0000
Willow Springs Solar 3 P393 0.0000
NAPA Self Storage 2 P394 0.0000
BCE Los Alamitos 1 P395 0.0000
BCE Los Alamitos 2 P396 0.0000
Zephyr Park c/o Oak Creek Wind Power, LLC P397 0.0000
SPVP 032 P398 0.0000
SPVP 033 P399 0.0000
SPVP005 RDC 1 P400 0.0000
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SPVP007 RDC 3 P401 0.0000
SPVP 027 P402 0.0000
SPVP 027 P403 0.0000
SPVP 044 P404 0.0000
SPVP 048 P405 0.0000
SPVP 026 P406 0.0000
SPVP 028 P407 0.0000
Marina Middle School Solar P408 0.0000
Alameda Creek Watershed Center Solar P409 0.0000
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Version: April 2024
Net MWh
Procured N/A Resource Type
Resource Mix
Factors
Resource-Specific
Procurements from ACS
20,757 Biomass & biowaste -
Geothermal -
Eligible hydroelectric -
Solar -
Wind -
Coal -
Large hydroelectric 0.84 17,364
Natural gas -
Nuclear 0.11 2,261
Other 0.01 177
Unspecified Power 0.05 955
Net MWh
Procured N/A Resource Type
Resource Mix
Factors
Resource-Specific
Procurements from ACS
5,280 Biomass & biowaste -
Geothermal -
Eligible hydroelectric -
Solar -
Wind -
Coal -
Large hydroelectric 0.89 4,723
Natural gas -
Nuclear 0.06 297
Other -
Unspecified Power 0.05 260
Bonneville Power Administration

ASSET CONTROLLING SUPPLIER RESOURCE MIX CALCULATOR
Tacoma Power
Instructions: Enter total net specified procurement of ACS system resources into cell A8 or A23.

In Column E, the calculator will determine quantities of resource-specific net procurement for entry on Schedule 1.
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Exhibit B – Power Content Label

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8b
24-86635

CITY OF GLENDALE, CALIFORNIA

REPORT TO THE CITY COUNCIL

AGENDA ITEM
Report: Plan to Increase Glendale Water and Power (GWP) Customer Solar Adoption and Develop Additional Distributed Energy Resources.

Plan to Increase Solar Adoption and Develop Additional Distributed Resources.

COUNCIL ACTION
Item Type: Action Item
Approved for November 19, 2024 calendar

EXECUTIVE SUMMARY
On November 15, 2022, the City Council adopted a Motion authorizing the General Manager of GWP to issue a Request for Proposals (RFP) seeking consulting firms to assist in developing a plan to increase solar penetration and develop additional Distributed Energy Resources (DER). Following a competitive selection process, E3 was selected to conduct an analysis aimed at achieving at least 10% solar and energy storage adoption among GWP customers, estimating dispatchable capacity, performing cost-benefit analyses, and developing a plan to meet these goals.

The E3 analysis assessed various solar and energy storage program scenarios for feasibility, equity, and costs. The findings concluded negative ratepayer impacts across all scenarios, indicating that the original goals set forth in Resolution No. 22-125 (a copy of which is attached to this Report as Exhibit 1), requiring at least 10% of GWP customers adopt solar and energy storage systems, and to develop additional demand management measures, with a minimum total peak dispatchable and peak-load- 106 of 559

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reducing capacity of 100 MW, are not feasible.

Given these study findings, staff recommends amending Resolution No. 22-125 to ensure GWP can continue its progress toward a clean energy portfolio while maintaining affordability for customers.

To address these challenges, staff proposes immediate program initiatives aimed at mitigating these negative impacts and supporting the City Council’s intent of Increasing Solar Adoption and Developing Additional DER (Plan). This Plan outlines three programs to enhance energy efficiency and reduce peak demand in alignment with GWP’s clean energy objectives, and staff recommends proceeding with designing and implementing these programs.

To meet Council’s request for additional community engagement and cover related E3 travel expenses, and to develop customized GWP avoided costs analysis, the project encountered budget overruns totaling $52,330. With Council’s approval to amend the PSA with E3, the additional $52,330 for this completed work will increase the total amount of the current PSA from $335,875 to $388,205.

RECOMMENDATION
Staff recommends that the City Council:

1. Accept the findings of the E3 study to inform GWP’s strategic direction.

2. Amend Resolution No. 22-125 to revise the solar energy goals, ensure continued affordability and reliability of energy services for the Glendale community, and approve the development of three proposed programs to enhance energy efficiency and reduce peak demand:
•In-System Solar Power Purchase Agreement (PPA) Program •Comprehensive Residential Energy Efficiency Rebate Program •Comprehensive Energy and Water Assessments, Installations, and Concierge Services

3. Approve the amendment to the existing PSA with E3 to increase the total amount by $52,330, to a new total not to exceed amount of $388,205.

ANALYSIS
On August 16, 2022, the City Council adopted Resolution No. 22-125, which among other things, declared the City of Glendale’s intent to adopt policies and practices designed to reach a goal of having at least 10% of GWP customers adopt solar and energy storage systems by 2027, and develop additional demand management measures, with a minimum total peak dispatchable and peak-load-reducing capacity of 100 MW. To support these goals, City Council directed staff to issue an RFP for consulting services.

On December 8, 2022, GWP issued an RFP and based on the results of a competitive selection process selected E3 to provide the following services:

Category 1: Develop a plan to achieve the goal of having at least 10% of GWP 107 of 559

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customers adopt solar and energy storage systems by 2027, and to develop additional demand management measures, with a minimum total peak dispatchable and peak- load-reducing capacity of 100 MW.

Category 2: Calculate the estimated dispatchable capacity and demand reduction that can be achieved through the plan developed in Category 1.

Category 3: Complete a cost benefit analysis including direct and indirect economic benefits and costs, as well as environmental, societal, and other noneconomic benefits and costs, and direct and indirect impacts to low- and moderate-income households. If the analysis concludes any negative impacts on low-and-moderate-income households, include program options to mitigate the impact.

As part of the analysis, E3 identified market segments and assessed the potential for solar and storage adoption, and developed hypothetical program designs and incentive options. Additionally, E3 evaluated and summarized the dispatchable capacity and peak load reduction potential by examining program adoption potential and impacts, and reviewing the GWP Integrated Resource Plan (IRP). E3 also conducted a cost-benefit analysis, which included developing GWP custom avoided costs.

The E3 study concluded that achieving the original goals by the specified percentages and timelines is not feasible without imposing significant financial burden on the community, especially for low- and moderate- income households. Therefore, revising these targets will allow GWP to continue progressing towards clean energy while ensuring affordability.

The E3 report summarizes findings across the three categories, highlighting the financial impacts. The E3 findings concluded that:

1. Achieving a goal of 10% customer solar adoption by 2027 is not feasible. The goal is theoretically feasible by 2030 with a significant increase in utility costs and effort, but real-world barriers remain.

2. Achieving a goal of 10% customer storage adoption in the near future is not feasible.

3. Achieving a goal of 100 MW of reliable peak load reduction with DERs is not feasible.

The cost-benefit analysis evaluated the participant cost test (PCT), societal cost test (SCT), and ratepayer impact measure (RIM). The RIM score indicated that program costs outweigh benefits, resulting in a negative ratepayer impact for all GWP ratepayers. While both the PCT and SCT scored positively, indicating bill savings for participants and significant societal benefits over the system lifetime, it is important to note that these costs would ultimately be absorbed by GWP ratepayers. The societal benefits, such as reduced emissions, are achieved by shifting costs onto GWP customers. Although participants benefit from bill savings and incentives, the RIM score emphasized that these scenarios may not be sustainable for the broader customer 108 of 559

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base, meaning the financial burden will disproportionately affect all ratepayers. As a customer owned utility, GWP needs to find other solutions that equitably distribute benefits across all customers.

Since the E3 study revealed significant challenges and projected substantial increases in utility costs which would result in additional rate increases and cost shifts to low- and moderate-income customers, staff recommends revising the goals established in the original Resolution No. 22-125 to ensure that GWP can meet its clean energy objectives without imposing additional undue financial burden on its ratepayers. Specifically, the amended resolution would revise the target of achieving 10% customer adoption of solar and energy storage by 2027 to a combined target of 60 MW of customer-owned, in-system PPA, and City-owned solar adoption by 2030. Below is a summary table of the current and projected solar generation capacities in Glendale.

Customer
Class
Number of
Connections
Current
Generation
Capacity (MW)
Projected Generation
Capacity (MW) by
2030
Residential Single Family 24,234 18.1 35
Non-Residential 9,869 11.2 15
Total Customer Owned Solar 87,281 29.3 50
Phase 1 & 2 Utility Owned Solar - 0 8*
Power Purchase Agreements - 0 2*
Total Solar Capacity - 29.3 ~ 60**
* In Progress
** 15% of Forecasted (380 MW) Total Peak Demand in 2030 With respect to the resolution language referencing 10% customer adoption of energy storage and to achieving a minimum total peak dispatchable and peak-load-reducing capacity of 100 MW by December 31, 2027, we recommend amending the resolution removing said language aligned with E3’s findings deeming them infeasible. The Community’s current progressive project deploying 75 MW/300 MWh of utility-scale energy storage will collect any excess system and solar energy and redeploy it during peak periods starting in the Summer of 2026. This project is already funded, will serve the whole of the Glendale community, and represents a capacity greater than 20% of Glendale’s highest peak-load day.

Given the analysis and findings, staff explored program options to increase DER adoption in the City. Staff seeks City Council acceptance of the E3 report, after which new programs will be developed that would require separate and additional approval by the City Council at the appropriate time.

Recognizing the importance of understanding community sentiment and priorities, E3 and GWP conducted a community survey as part of the community outreach that gathered over 2,000 responses. Affordability emerged as the top priority, alongside concerns about potential rate increases. The insights gained from this survey will guide 109 of 559

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the design and implementation of customer programs to meet the needs of the community while seeking alignment with the City Council’s goals.

To achieve the objectives of enhanced demand management, GWP plans to promote increased DER adoption, and grid reliability while ensuring affordability. GWP is committed to facilitating the adoption of solar, storage, and other DER technologies through effectively managing cost shifts and making the transition affordable for all customers, ultimately fostering a cleaner and more sustainable future for Glendale.

The E3 study revealed that transitioning to a net billing tariff (NBT) or net energy metering (NEM) 3.0 is necessary for better managing cost shifts associated with the integration of DER technologies. NBT would allow for a more equitable allocation of costs among all customers. In contrast, the current NEM programs, such as NEM 1.0 and NEM 2.0, overcompensate for the benefits provided and fail to reflect the true costs of solar and storage. In general, this misalignment contributes significantly to rates increases throughout the state, placing an undue burden on non-solar customers, such as renters and lower-income households, and could hinder the state’s electrification efforts if not addressed.

Recent finding from the Public Advocates Office estimate that NEM will cost customers without solar an estimated $8.5 billion by the end of 2024, a figure that has more than doubled since 2021.

Graph sourced from California’s Public Advocates Office report titled “Rooftop Solar Incentive to Cost Customers Without Solar an Estimated $8.5 Billion by the End of 2024.” Available at:
https://www.publicadvocates.cpuc.ca.gov/-/media/cal-advocates-website/files/press-room/reports-and- analyses/240822-public-advocates-office-2024-nem-cost-shift-fact-sheet.pdf However, GWP recognizes the Council’s desire to increase solar penetration and is not yet prepared to transition to an NBT. GWP needs to further evaluate the implications and ensure that our infrastructure and customer support systems are equipped to handle this change effectively. Therefore, GWP will continue to support NEM 1.0 for customer owned solar as it is presently represented in Glendale. GWP will continue to promote solar technology adoption as staff works toward a more effective solution for 110 of 559

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managing existing cost shifts in the future. In the meantime, as indicated in the graph below, the current NEM 1.0 program continues to grow even without incentives.

To support increased DER adoption, staff have identified and seeks City Council approval to design and implement the three programs below that will facilitate effective energy demand management in support of our clean energy future:
•In-System Solar Power Purchase Agreement (PPA) Program •Proposed Launch: November 2025
•Overview: This program aims to guarantee long-term rates and enhance understanding of return on investment (ROI). It will also explore providing location-specific incentives for utilization of underutilized spaces. •Comprehensive Residential Energy Efficiency Rebate Program •Proposed Launch: August 2025
•Overview: This program will offer increased incentives for energy efficiency measures to support the adoption of more DER. Lower upfront costs will help customers adopt more above-code technology.
•Comprehensive Energy and Water Assessments, Installations and Concierge Services
•Proposed Launch: January 2026
•Overview: This program will provide comprehensive energy and water assessments, direct installation of measures, and concierge services to help customers identify additional local, state, and federal incentives for additional home energy and water upgrades.
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Projected solar adoption in Glendale by 2030, considering current customer adoption trends, the proposed In-System PPA Program, and the planned Utility Owned Solar Program is projected to be around 60 MW. This represents around 15% of the forecasted total peak demand for 2030 and is double the current solar generation capacity.

With City Council approval, staff will proceed with the design of the proposed programs, conducting further analysis to identify cost-effective energy and water efficiency measures, and to quantify additional achievable energy efficiency savings for these proposed programs.

To meet Council’s request for additional community engagement and cover related E3 travel expenses, and to develop customized GWP avoided costs analysis, the project encountered budget overruns totaling $52,330. The additional $52,330 for this completed work increased the total amount of the original PSA from $335,875 to $388,205.

A significant factor in this increase was the additional effort E3 dedicated to community meetings. In response to City Council’s request during the contractual phase, from the total budget of $97,080 allocated to community outreach and engagement, $79,500 was used toward Dakota Communications’ staff and marketing materials to ensure effective community outreach and engagement. That left only $17,580 for E3 and Willdan staff.

Dakota communications oversaw community engagement and managed the logistics for five community meetings. This included creating, designing, and implementing all marketing materials, translating documentation into multiple languages, and conducting outreach through various communication channels.

Each community meeting required 40-50 hours of work from the E3 and Willdan teams, involving the development and refinement of presentation materials, incorporating feedback from GWP, and polishing final presentations. Specifically, enhanced outreach efforts included additional time spent preparing for the initial three meetings, including creating breakout room discussions with four posters. For the fourth and fifth meetings, E3 focused on developing a new set of slides based on feedback from the initial community meetings, ensuring they were clear, engaging and informative. This increased effort resulted in an additional budget extension of $33,330 to cover the additional time and resources dedicated to community meetings and engagement. The additional community meetings also increased travel costs by $3,000.

Additionally, the rejection of the original Integrated Resource Plan increased the workload and complexity of developing GWP avoided costs, resulting in an additional $16,000 for the necessary adjustments and updates to the study.

Glendale Water & Power Commission Recommendation:

A summary of the E3 Report was presented to the GWP Commission on October 7, 2024 for their initial discussion and consideration so that they could make their 112 of 559

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recommendation to the City Council. Out of consideration for the Commission’s desire to review and digest the full draft report, it was made available for public review on October 17, 2024 via the project website. Notifications were provided to each Commissioner about the posting including the related link, as well as provided to interested community members associated with the Glendale Environmental Coalition.

At the following GWP Commission meeting held on November 4, 2024, in full consideration of the additional time and discussion the Commissioners had to review the E3 Report and GWP staff’s recommendations, the GWP Commission recommended that the City Council accept staff’s recommendations outlined in this Report. The GWP Commission Motion capturing the details of this recommendation on November 4, 2024 is attached as Exhibit 3.

STAKEHOLDERS/OUTREACH
Not applicable.

FISCAL IMPACT
The extra cost for E3’s additional work can be absorbed within the approved budget for fiscal year 2024, as there are unspent funds available to offset this expense. The current PSA with E3 is for a total amount not to exceed $335,875. Amending the PSA to include an additional $52,330 for additional completed work will increase the total amount to $388,205.

The proposed Comprehensive Residential Energy Efficiency Rebate Program and the proposed Comprehensive Energy and Water Assessments, Installations and Concierge Services Program will be designed to achieve a zero net impact on the budget by reallocating and optimizing various programs within the existing Public Benefit Charge- funded programs portfolio.

Existing Appropriation
Amount Account String Funding Source
$52,330 GL: 43110-5820-GWP-4520 Electric Works Revenue Fund

ENVIRONMENTAL REVIEW (CEQA/NEPA)
The action herein is not a project for the purposes of the California Environmental Quality Act (CEQA) and as such CEQA is not applicable.

CAMPAIGN DISCLOSURE
The names and business addresses of the members of the board of directors, the chairperson, CEO, COO, CFO, Subcontractors and any person or entity with more than 10% interest in the company proposed for contract in this Agenda Item Report are attached in Exhibit 4, in accordance with the City Campaign Finance Ordinance No. 5744.

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ALTERNATIVES TO STAFF RECOMMENDATION
Alternative 1: Choose not to accept the findings of the E3 study, not to approve the development of the three proposed programs, not to amend the original Resolution No. 22-125 and/or not to approve the PSA amendment request of $52,330.

Alternative 2: Consider any other alternative not proposed by staff.

ADMINISTRATIVE ACTION
Submitted by:

Manuel Robledo, Interim General Manager - Glendale Water and Power Prepared by:

Scott K. Mellon, Assistant General Manager - Power Management Ruzan Soloyan, Clean Energy Officer
Approved by:

Roubik R. Golanian, P.E., City Manager

EXHIBITS/ATTACHMENTS
Exhibit 1: Resolution No. 22-125
Exhibit 2: E3 Study Report: Plan to Increase Solar Adoption and Develop Additional Distributed Resources
Exhibit 3: Glendale Water & Power Commission Motion
Exhibit 4: Campaign Finance Disclosure for E3
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M O T I O N
Moved by Council Member ________________________________, seconded by Council Member __________________________________, that the City Council has considered the Final Report: Plan to Increase Solar Adoption and Develop Additional Distributed Resources (E3 Final Report) prepared by Energy Environmental Economics, Inc. (E3) as a result of E3’s study on Glendale Water & Power Department’s (GWP) plan to increase solar adoption and develop additional distributed energy resources, as described in the Report Dated November 19, 2024 by the Interim General Manager of GWP, and hereby accepts the findings of the E3 Final Report.

Vote as follows:

Ayes:

Noes:

Absent:

Abstain:
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M O T I O N
Moved by Council Member ________________________________, seconded by Council Member __________________________________, that the City Council hereby authorizes the City Manager, or his designee, to execute an amendment to the existing Professional Services Agreement (PSA) with Energy Environmental Economics, Inc. (E3), contract no. C8002375, to increase the PSA not to exceed amount by $52,330 for additional completed work and authorize the corresponding encumbrance. The City Manager, or his designee, is authorized to execute said amendment subject to approval by the City Attorney.

Vote as follows:

Ayes:

Noes:

Absent:

Abstain:
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Glendale Water and Power’s Plan to Increase
Solar Adoption and Develop Additional
Distributed Energy Resources
November 6, 2024
E3 Study Report
Eric Cutter, Partner
Jun Zhang, Senior Managing Consultant
Sierra Spencer, Managing Consultant
Fangxing Liu, Senior Consultant
Brendan Mahoney, Senior Consultant
Hannah Platter, Consultant
Parker Wild, Consultant
Lindsay Bertrand, Senior Managing Consultant
Exhibit 2
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2 Table of ContentsExecutive SummaryIntroductionCommunity Outreach & EngagementE3 Analyses & Findings•DER Technical Potential & Market Segmentation in Glendale•Dispatchable Capacity and Demand Reduction Capacity•Customized Avoided Costs for GWP•Adoption and Impact Analysis•Cost and Benefit Analysis•Potential Program and Policy OptionsDiscussionAppendix Objective Assessment of Costs and BenefitsE3 presents a non-technical assessment of the costs of achieving GWP's clean energy goals. This assessment does not specify who will bear these costs but focuses on outlining the various costs, benefits, and perspectives covered in the report.Information for Decision-MakersThis report analyzes the adoption of various program portfolios and illustrates the trade-offs of different options. It provides essential information to enable community members, the City Council, and the Commission to make informed recommendations regarding the benefits, costs, and feasibility of alternative approaches to achieving GWP's clean energy goals and striking the right balance for the City.Program Design AlternativesThis report describes various program design alternatives rather than specific recommendations. Detailed technical analyses are included later in the report for those interested in the supporting data. 134 of 559

3 Energy EfficiencyElectric VehiclesCustomer-Sited SolarFlexible LoadsEnergy StorageDemand Response Glossary: Types of DERs (Distributed Energy Resources)
And More…
Load ReducingLoad ShiftingLoad Increasing
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4 Glossary: Levels of DER PotentialÊTechnical Potential is a metric that quantifies the maximum generation or capacity available for a technology in each region and does not consider the economic or market viability.ÊEconomic Potential applies a cost-effectiveness screen to each measure; only cost-effective measures are included in the economic potential (usually from total resource cost or societal perspectives).ÊAchievable Potential refines technical and economic potential by applying customer participation rates that account for real-world constraints, policy levers, and the likelihood of adoption.

Not Technically FeasibleNot Cost-Effective
Not Technically FeasibleNot Achievable
Technical PotentialTheoretical maximum generation or capacity available Economic PotentialEconomically cost-effective according to specific criteria Achievable PotentialPractical estimate considering real-world barriers Not Technically Feasible
Not Cost-Effective
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5 ÊACC: Avoided Cost CalculatorÊBESS: Battery Energy Storage SystemÊCAISO: California Independent System OperatorÊCEC: California Energy CommissionÊC&I: Commercial & IndustrialÊCPUC: California Public Utilities CommissionÊDR: Demand ResponseÊEE: Energy EfficiencyÊELCC: Effective Load Carrying CapabilityÊEV: Electric VehicleÊFL: Flexible Load ÊGWP: Glendale Water & PowerÊIOU: Investor-Owned UtilityÊLDEV: Light-Duty Electric VehicleÊLOLH: Loss of Load HoursÊLOLP: Loss of Load ProbabilityÊMF: Multi-FamilyÊPV: PhotovoltaicÊRA: Resource AdequacyÊSF: Single-FamilyÊV1G: Vehicle-to-Grid, one-way power flowÊV2G: Vehicle-to-Grid, two-way power flowÊVGI: Vehicle Grid Integration Glossary: Other Acronyms
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Section 1Executive Summary
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Introduction
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8 ÊE3 is the largest consulting group focused on the clean energy transition in North AmericaÊE3 is a recognized thought leader on decarbonization and clean energy transition topicsÊE3 has four major practice areas covering energy systems from bulk grid to behind the meter Who is E3?
•Valuation of DERs•DER dispatch and asset optimization•Rate design•Grid modernization•Building electrification•Vehicle electrification •Integrated resource planning for electric systems: reliability and resource mix•Planning for utility and state RPS + GHG targets•Utility planning and procurement decisions DER / Electrification / RatesIntegrated System Planning Economy-wide energy systemsBulk grid power systemsGrid edge & behind-the-meter •Climate and energy policy analysis•Long-term energy & climate scenarios•Electrification and low-carbon fuels •Future of gas Climate Pathways / Policy Analysis
•Asset valuation and due diligence•Strategic advisory•Energy market price forecasting•Market design•Transmission planning Asset Valuation & Strategy
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9 Introduction and Objectives
Category 1Develop Plan to Increase Solar and Energy Storage Penetration and Develop Additional Distributed Energy Resources (DERs) Category 2Dispatchable Capacity and Demand Reduction Calculation Category 3Cost-Benefit Analysis
10% of GWP customer solar and energy storage adoption by 2027Additional dispatchable and peak load reduction capacity of 100 MW City Council Resolution of August 2022
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10 GWP partnered with E3 to create an equitable solar and energy storage adoption plan with input from the community, focusing on community outreach and ensuring that multifamily and rental properties are thoroughly incorporated into the plan.

Under direction from the City Council, Glendale Water & Power issued an RFP focusing on three key categories of analytical support Category 1Develop Plan to Increase Solar and Energy Storage Penetration and Develop Additional DERs Category 2Dispatchable Capacity and Demand Reduction CalculationCalculate the estimated dispatchable capacity and demand reduction that can be achieved through the plan developed in Category 1.

Category 3Cost-Benefit AnalysisComplete an analysis of the benefits and cost of the plan developed in Category 1, and the analysis must include:•Direct and indirect economic benefits and costs, as well as environmental, societal, and other noneconomic benefits and costs; and direct and indirect impacts to low- and moderate-income (LMI) households.•If the analysis concludes any negative impact, the consultant shall include program options to mitigate the impact.•If the analysis concludes that there are any negative impacts on LMI households, the consultant shall include program options to fully mitigate the impact.

Develop a plan to achieve the goal of having at least 10% of GWP customers adopt solar and energy storage systems by 2027, and to develop additional demand management measures, with a minimum total peak dispatchable and peak-load-reducing capacity of 100 MW by December 31, 2027.If the consultant concludes that date to be unattainable then a date identified soon thereafter. The plan must include policies and incentives designed to be sufficient to ensure customers will adopt solar and energy storage at a rate that achieves the adoption and capacity goals stated above. The plan must include an alternative approach with a mix of storage at customer sites and at GWP-controlled sites, rather than all storage being located at customer sites.

Potential Policies and IncentivesNet Energy Metering (NEM)Upfront RebatesFeed-In-Tariff (FIT) ProgramPerformance-Based IncentivesEquity Strategies & PoliciesCommunity Solar ProjectsEnergy EfficiencyDemand Reduction 142 of 559

11 E3’s analytical support focused on several research questions How can local solar and distributed energy resources be effective, economic, and equitable parts of GWP’s reliable, low-carbon resource portfolio? Encouraging Customer Adoption
Realizing Value for Grid & CommunityManaging Cost-Shift & Affordability Balancing Multiple Objectives

1. What is the potential for solar, energy storage, and other DER adoption in meeting the City Council's goals?2. If the goals are not currently achievable, when can they realistically be met?3. What policies and incentives are necessary to achieve the adoption and capacity goals and their cost/benefit implications?4. How can policies and incentives be tailored to address the needs of low-income customers, residents in heavily pollution-burdened areas, multifamily properties, and rental properties?5. What are the direct and indirect economic, environmental, societal, and other non-economic benefits and costs associated with solar, energy storage, and other DER adoption?6. What are the direct and indirect impacts on low- and moderate-income (LMI) households resulting from these policies and incentives? 143 of 559

12 ÊE3 submitted a proposed budget and scope of work that we felt most cost-effectively met Glendale’s objectives, but did not provide all the deliverables requested (slide 10).ÊIn response to input from the community and City Council, scope of work was shifted to increase emphasis on community outreach and the number of stakeholder meetings. The shift in scope included:•Reducing the level of effort for program design recommendations•Focusing on solar and storage and not evaluating other DERs in depth ÊE3 developed and recommended program options that would help the City achieve its goals in a more cost-effective and equitable manner than net energy metering (NEM) alone.

1. Develop Plan to Increase Solar and Storage AdoptionüIdentify market segments and potential for solar and storage adoptionüDevelop program design and incentive recommendationsüPerform community outreach and engagement2. Evaluate Dispatchable Capacity and Peak Load Reduction PotentialüSummarize program adoption potential and impactsüReview GWP Integrated Resource PlanüSummarize dispatchable capacity and peak load reduction potential3. Perform Cost-Benefit AnalysisüDevelop avoided costs for DERüPerform cost-benefit analysis Revised Scope of WorkRevised Scope of Work Completed by E3 144 of 559

13 E3 designed the following workflow to support the adoption plan development Estimation of DER potential from all market segments
Enhancement of avoided costs to reflect GWP system plans and characteristics Analysis of adoption scenarios to identify the feasibility of City Council targets and short-list the most promising and effective policy and program options Benefit cost analysis considering direct/indirect economic and non-energy benefits; outline cost and benefit implications of all possible adoption strategies and alternatives to inform GWP’s decision-making process Deep dive into program options to provide program recommendations that balance customer adoption, customer affordability, and achieving value for the whole Glendale community 145 of 559

Utility Challenges and Opportunities
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15 Role of Local Clean Energy Resources
GWP faces many challenges in transitioning to a cleaner grid, and local clean energy resources could provide significant support Glendale's Clean Energy Vision•60% RPS by 2030 (CA regulatory requirement)•100% Clean Energy by 2035 (Glendale goal)Transmission & Land Constraints•Procuring new renewables outside of the City•Procuring new renewables within the CityIntegrated Resource Plan (IRP) Planning Challenges•Integrating renewables, coal retirement, and hydrogen combustion turbine (CT) conversion•Maintaining system reliability Maintaining leadership in clean and renewable energy
Unlocking more local generation
Reducing fossil fuel generation (Grayson Repower, etc.) System Context and Challenges
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16 Turning potential into adoption requires a multifaceted approach to ensure equitable solar and DER adoption in Glendale Community Outreach
Permitting, Interconnection, and Approval Rules & Process Program & Incentive Design
Equity Strategies
Additional DR, EV, and EE Strategies
Utilize modeling and scenario analysis to evaluate and identify effective, least-cost, and equitable strategies, along with improved and customized avoided cost valuation and cost-benefit analysis for GWP These are the prerequisites for encouraging more adoption – incorporate community inputs and E3/Willdan project experience and expertise Energy Efficiency
Customer-Sited SolarEnergy Storage
Electric Vehicles
Flexible LoadsDemand Response
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17 Turning potential into adoption requires a multifaceted approach to ensure equitable solar and DER adoption in Glendale Community Outreach
Permitting, Interconnection, and Approval Rules & Process Program & Incentive Design
Equity Strategy
Demand Response, Electric Vehicles, and Energy Efficiency Utilize modeling and scenario analysis to evaluate and identify effective, least-cost, and equitable strategies, along with improved and customized avoided cost valuation and cost-benefit analysis for GWP .

These are the prerequisites for encouraging more adoption – incorporate community inputs and E3/Willdan project experience and expertise •Additional outreach on federal and state support (e.g., Inflation Reduction Act, Self-Generation Incentive Program, etc.)•Propose adoption programs that use mechanisms that customers intuitively understand•Comprehensive outreach and knowledge campaigns from GWP to inform and educate residents•Intelligible program design •Faster, easier, and scalable permitting, interconnection, and approval process •Additional incentive and program considerations for low- to moderate-income (LMI) customers, disadvantaged communities (DACs), and pollution-burdened areas•Balance expanding solar access with minimizing cost shifts to non-adopters via community solar, virtual solar, and financing programs •Analysis of adoption scenarios to identify the feasibility of City Council targets •Short-list the most effective policy and program options that move towards the targets with improved equity and lower costs•Provide policy and program option alternatives to guide the direction for effective program design •Provide program and incentive options to further promote other DER technologies Requires additional studyFocus of this reportFocus of this report 149 of 559

Summary of Findings and Recommendations
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19 ÊNEM compensation for customer-owned solar will increase GWP electric rates for all customers by 6% in 2030 ($0.02/kWh)ÊCustomer solar adoption under NEM is predominately by single-family homeownersÊCustomer-owned solar and storage under NEM provides limited peak capacity reduction•The effective capacity of solar and storage is less than 10% and 50% of the installed capacity, respectively Encouraging customer adoption of solar and storage must be balanced against other municipal utility objectives Encouraging Customer Adoption
Realizing Value for Grid & CommunityManaging Cost-Shift & Rate Affordability Under NEM, customer adoption of solar and storage provides limited grid value and increases rates for all customers 151 of 559

20 Findings: Achieving the adoption goals by 2027 is not feasibleAchieving a goal of 10% customer solar adoption by 2027 is not feasible. The goal is theoretically feasible by 2030 with a significant increase in utility costs and effort, but real-world barriers remain.Achieving a goal of 10% customer storage adoption in the near future is not feasible. Achieving a goal of 100 MW of reliable peak load reduction with DERs is not feasible.

Recommendations§Set an adoption goal in terms of MW of installed capacity rather than a percentage of customers.§Perform additional analyses of realistically achievable potentials for customer-owned, community, and utility-scale solar and storage.§Develop an integrated resource plan with the potential and MW targets for each resource type.

Industry studies suggest that achievable potential is 20%-40% of the technical potential. 152 of 559

21 Findings: Adoption of customer-owned solar and storage increases GWP rates The scenarios achieving 10% solar adoption would result in a projected net cost of $23-$45 million to GWP ratepayers from 2024 to 2027. §Implement a Net Billing Tariff to reduce the cost shift.§Develop and implement non-bypassable charges and fixed customer charges to reduce the cost shift.§Evaluate the cost and feasibility of changes to GWP’s billing and metering systems needed to implement a Net Billing Tariff.

The resulting rate increase would be 6-11% by 2030, with a low- and moderate-income (LMI) customer monthly bill increase of $4-$6.

Recommendations
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22 Findings: Current customer-owned solar and storage adoption is predominately by single-family homeowners above the median incomeCustomer solar adoption in Glendale to date is above 10% for single-family homes and below 1% for renters and LMI customers.84% of customer solar adoption is in households above the median income. 88% of customer solar adoption is by property owners.
90% of customer solar adoption is in single-family homes. §Allow lower cost community solar and storage to count towards achieving the adoption goal.§Evaluate virtual solar programs that renters and LMI customers can subscribe to.§Evaluate the cost and feasibility of changes to GWP’s billing and metering systems needed to implement virtual solar programs.

Recommendations
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23 Findings: Customer-owned solar and storage provides limited reliable peak capacity reduction §Implement TOU rates that encourage customer storage adoption and dispatch for peak capacity reductions.§Study and expand demand response, electric vehicle, energy efficiency, utility dispatchable DER, and other programs for peak load reductions.§Evaluate the cost and feasibility of changes to GWP’s billing and metering systems needed to implement TOU rates and utility dispatchable DER.

The effective capacity of customer-owned solar is less than 10% of the installed capacity.

The effective capacity of customer-owned storage is less than 50% of the installed capacity.The maximum projected reliable peak load reduction from customer-owned solar and storage is 10 MW by 2027. When including other DERs such as demand response, managed electric vehicle charging, and energy efficiency, the maximum projected reliable peak load reduction is 44 MW by 2027.Recommendations 155 of 559

24 Findings: Additional costs not included in this study will be required §Evaluate Glendale-specific program elements that will be the most effective for increasing DER adoption by renter, LMI, and DAC customers.§Evaluate the cost and feasibility of necessary changes to GWP’s billing and metering systems.§Consider the cost of additional program overhead and customer outreach.

Achieving the 10% customer solar adoption goal by 2030 will require increasing the pace of annual adoption from 438 customers last year to over 1,000 customers per year.Community feedback requested enhanced customer outreach and support as well as a streamlined permitting process.Additional overhead and incentives will be needed to reach renters, LMI, and DAC customers that face larger barriers to solar and storage adoption. Changes to GWP billing and metering systems will be required.

Recommendations
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Current Solar and Storage Adoption Status
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26 ÊGlendale has 2,900 customer-sited solar systems totaling 28 MW, most of which are owner-occupied, single-family, non-LMI households. Solar penetration is currently at 3.25% and solar system installations in Glendale have been increasing every year, despite the end of the solar incentive program in 2022.

Glendale’s current solar and storage penetration pattern skews towards single-family, owner-occupied, and non-LMI households

0.0% 2.0% 4.0% 6.0% 8.0% 10.0%12.0%
SF
C&I
MF
Historical Solar Penetration (%)
Customer Sector

0.0% 2.0% 4.0% 6.0% 8.0% 10.0%
Own
Re ntOwnership

0.0%1.0%2.0%3.0%4.0%5.0%6.0%
LMI
Non-LMIIncome Level
Single family (SF) sector has noticeably higher customer solar penetration, followed by commercial & industrial (C&I) and multi-family (MF) sector Owner-occupied buildings have noticeably higher customer solar penetrationNon-LMI customers have noticeably higher customer solar penetration Adoption Level (% of Total GWP Electric Customers)
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27 ÊGlendale has less than 200 customer-sited storage systems, totaling 3 MWh. Most of these systems are owner-occupied, single-family, non-LMI households, with just one large system from commercial customers and none from multi-family residences, reflecting adoption barriers for renter and LMI customers.

Glendale’s current solar and storage penetration pattern skews towards single-family, owner-occupied, and non-LMI households

0.0% 0.2% 0.4% 0.6% 0.8% 1.0%
C&I
MF
SF
Customer Sector

0.0% 0.1% 0.2% 0.3% 0.4% 0.5% 0.6%
Own
Re ntOwnership

0.0% 0.1% 0.2% 0.3% 0.4%
LMI
Non-LMIIncome Level
SF sector has noticeably higher customer solar penetration, while MF and C&I observed minimal adoption Owner-occupied buildings have noticeably higher customer storage penetrationNon-LMI customers have noticeably higher customer storage penetration Adoption Level (% of Total GWP Electric Customers)
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28 A 10% adoption target for customer solar and storage is ambitious, and could require significant investments City of Glendale
2027 Solar Adoption Target
2027 Battery Storage Adoption Target
City of Glendale
Utility
Solar Adoption
(% of total electric
customer)
Battery Storage
(% of total electric
customer)
City of Burbank Water and Power 3.0% 0.0%
City of Pasadena 3.9% 0.0%
Los Angeles Department of Water & Power 5.4% 0.3%
City of Glendale 3.1% 0.2%
•Compared to peer utilities in the LA region and California, GWP ranked average for solar adoption and top-tier for storage adoption (as a percentage of total electric customers).•However, the 10% adoption targets by 2027 - if considered as separate goals for solar and storage - are ambitious for most California utilities, given current adoption levels. •Meeting these targets may require significant investments to accelerate DER adoption within the limited timeframe.NEM Installations as % of Total Electric Customers Utility-level net metering solar and storage installation and customer count data collected and derived from EIA Form 861 2023 early release version: https://www.eia.gov/electricity/data/eia861/ Selected CA Utilities (available in EIA 861 2023ER) 160 of 559

29 Solar Adoption and Rebate Trends: 2001 - 2024
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Customer Demographics
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31 ÊHigher income customers tend to adopt larger systems. •California residents tend to install smaller systems than other states, with median sizes ranging from 5.6-7.2 kW-DC across income levels.

ÊHigher income customers are more likely to adopt paired batteries. •California residents tend to adopt paired batteries at a higher rate than other states, with attachment rates ranging from 6%-19% across income levels.

Understanding the demographics of residential adopters in California provides crucial context for shaping GWP’s future in solar and storage Source: Lawrence Berkeley National Laboratory
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32 Glendale's solar adopters have higher incomes than the county, state, and national averagesLBNL Income Demographics of GWP Solar Adopters: Raw Income, Area Median Income 18%*
* General pop. data (includes non-adopters) is less granular, so households with incomes > $200k are shown in green/blue Share of 2016-2022 Solar Adopters by IncomeShare of 2016-2022 Solar Adopters by County Area Median Income (AMI) Source: Lawrence Berkeley National Laboratory (LBNL)
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Impact of Net Energy Metering (NEM) and Net Billing Tariff (NBT) on GWP Rates 165 of 559

34 Rate Increase
Compensation for rooftop solar increases retail rates for all GWP customers Utility Costs Not Avoided by Solar
Avoided by Utility-Scale Solar
Avoided by Customer Solar
Not Utility Costs
Utility Costs Avoided by Solar
NEM 1.0 Cost Shift
Solar Benefits
Environmental & Societal*
Energy, GHG, Some Capacity
Some Transmission & Distribution
NEM 1.0 Bill Savings
Rate Increase
Utility Costs Not Avoided by SolarUtility Costs Avoided by Solar NBT Cost Shift
NBT Bill Savings
*Also provided by lower cost community and utility-scale solar 166 of 559

35 California’s NEM Cost Shift and Solar Adoption Post NBT Source: https://www.californiadgstats.ca.gov/charts/
NEM PV Installations
Energy Storage Installations
Net Billing Tariff
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36 Parking Lots
Landfill
Industrial
Municipal
High Desert
Agricultural
Scrubland
Multiple types of solar and storage installations are available for GWP , with different cost implications Customer-OwnedCommunityUtility- Scale
Residential
Commercial
Rooftop
Community
Utility-Scale
Counts Towards 10% Customer Adoption Goal
Lower-Cost Alternatives with Similar Environmental Benefits $/kW System Cost
•Hillside solar is not considered by GWP.•Community solar in practice can involve large rooftop installations as well. 168 of 559

37 Customer-owned solar and storage is more expensive; lower cost alternatives provide similar environmental benefits •Modeled Market Price (MMP) Benchmarks from NREL Q1 2023 Customer-OwnedSolar + Storage
CommunitySolar + Storage
Utility-ScaleSolar + Storage
$4,700
$2,900$2,10040%
120%
$/kW Cost
60%
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38 Additional benefits for community and customer-owned solar over utility-scale solar exist, but do not outweigh the cost premium ÊRooftop Solar•All Benefits of Community Solar•Customer Reliability•Increased Home Value•Others ÊCommunity Solar•Transmission & Distribution (T&D) Investment Reduction•T&D Line Loss Reduction•Reduced Land Use Impacts•Local Reliability, Resilience•Local Jobs Customer-Owned
Community
Plus
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Technical Potential Analysis
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40 ÊRooftop Solar: 313 MWÊParking Canopy Solar: approx. 300 MWÊGround-Mounted Solar: approx. 27 MW Technical Potential of Rooftop, Parking Canopy, and Ground-Mounted Solar in the City of Glendale Rooftop Solar: 313Parking Canopy Solar: 300Ground-Mounted Solar: 27 Technical potential is a metric that quantifies the maximum generation or capacity available for a technology in a given region and does not consider the economic or market viability.Variations in the definition of technical potential and assumptions in filtering criteria may impact results substantially.

Rooftop solar technical potential for the entire City of Glendale, including city-owned properties 172 of 559

41 ÊGWP conducted site-specific analyses on over 100 city-owned properties for potential large-scale rooftop, parking canopy, and ground-mounted solar projects•Over 60 sites are deemed feasibleÊMost sites are filtered out due to their project size of less than 100 kW each and various other developmental constraints, for example:•Not solar ready•Solar not advised by property owners•Historical or community use•Pending roof, structural, reconstruction, ADA, and feeder upgradesÊGWP has identified 10-15 large city-owned sites for developing solar projects•Collectively 10 MW of solar capacity•Six projects approved for construction (5 MW) Achievable solar and storage potential for city-owned properties must account for additional real-world constraintsTechnical Potential of Rooftop, Parking Lot, and Ground-Mounted SolarTotal Analyzed16 MWSolar Ready10 MW 5 MW
•Additional sites evaluated after the initial round of solar site analysis were not included. 6 Sites
10-15 Sites
100+ Sites
Approved for Construction
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42 Ê75% of total roof space (based on building footprint) is considered developable for rooftop solar•Accounts for setback factor required by LA County, as well as potential obstructions; based on research conducted for NREL’s LA100 studyÊSolar potential based on 110% of customer’s annual load•Assuming 20% capacity factor (DC), based on default system parameters from NREL’s PVWatts tool for Glendale•Module power density of 160 W/m2 (approximately 14.86 W/sq. ft.), in line with NREL REPLICA estimate for flat roofs ÊNumber of buildings suitable for solar adjusted to 79.25%•Based on Project Sunroof data for Glendale; accounts for factors such as structural stability of roof and electrical code complianceÊStorage potential aligns with maximum DER ratings allowed by GWP for solar and storage systems•Assume only customers with non-zero solar technical potential are considered eligible to install storage•Minimum storage potential is 30 kWh; if solar potential exceeds 10 kW, maximum storage potential of 110% of the historical average daily usage Rooftop Solar and Customer Battery Storage Technical Potential in Glendale (E3 Mid-Case) Note: These figures represent the theoretical maximum of solar and storage capacity under applicable policies and other constraints. In the adoption analysis, systems were sized based on customer needs. 95 MW30%5 kWdc/cust
86 MW27%2 kWdc/cust
132 MW42%18 kWdc/cust
For Mid-Case
Rooftop Solar Potential in Glendale
559 MWh63%29 kWh/cust
216 MWh24%4 kWh/cust
115 MWh13%15 kWh/cust For Mid-Case
Battery Storage Potential in Glendale
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43 Single-FamilyMulti-FamilyCommercial & Industrial
For Mid-Case, in MWSolar Potential by Sector, Ownership Status, and Building Type E3 estimates identify 313 MW GWP solar potential from all market segments (E3 Mid-Case) * Omits sites that could not be categorized
Key Observations•Single-Family: Owner-occupied single-family residences show the greatest potential for adoption. •Multi-Family: Multi-family rental properties follow closely behind but face challenges due to ownership dynamics and split incentives between owners and tenants. Addressing these issues could unlock significant potential. •Commercial & Industrial: While comprising fewer customers, these sectors have larger average installation sizes, making them significant contributors to achieving the 100 MW DER capacity target. 175 of 559

44 Single-FamilyMulti-FamilyCommercial & Industrial
For Mid-Case, in MWhStorage Potential by Sector, Ownership Status, and Building Type E3 estimates identify 900 MWh GWP storage potential from all market segments (E3 Mid-Case) * Omits sites that could not be categorized
Key Observations•Single-Family: Owner-occupied single-family residences show the greatest potential for adoption. Customers with less than 10 kW solar systems can install up to 30 kWh battery storage systems.•Multi-Family: Multi-family rental properties follow closely behind but face challenges due to ownership dynamics and split incentives between owners and tenants. Addressing these issues could unlock significant potential.•Commercial & Industrial: For large solar systems (>10 kW), maximum storage potential is up to 110% of the historical average daily usage, which constrains the potential from the C&I sectors. 176 of 559

Scenario Overview
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46 Scenario 1: Continue NEMScenario 2: Targeted LMI/DACs & MF AdoptionScenario 3: BalancedScenario 4: Widespread Adoption E3 evaluated four program scenarios to identify target feasibility and show trade-offs in adoption, equity, and costsNEM CompensationAdditional IncentivesAccess for Renter and LMI CustomersProvide More Utility Support Program & Incentive Design
Address Additional Barriers•Low and Moderate Income (LMI)•Disadvantaged Communities (DACs)•Multi-family (MF) 178 of 559

47 Other Utility Support
The scenarios outline different pathways towards Glendale’s DER adoption targetNEM CompensationAdditional Incentives*Renter and LMI Customer Barriers S1S2Targeted LMI MF Adoption
S3Balanced
S4Widespread Adoption
S5Direct Install
Net energy metering at retail ratesNet energy billing at avoided costs Net energy metering at retail rates
Net energy metering at retail rates
Net energy billing above avoided costs but below retail rates Federal and stateFederal and state, utility direct install for LMI/DAC MF customers Federal and state, and direct install for MF renter LMI/DAC customers Federal and state, 5-yr payback utility incentive for all MF customers Federal and state, 7-yr payback utility incentive for LMI/DAC MF buildings Persist
Optimistic outlook on enhanced community outreach and support, along with improved permitting processes starting early 2025 Optimistic outlook for providing renter and LMI customer solutions starting early 2025 S0Business as UsualNet energy metering at retail ratesFederal and statePersistAt the Current Level PersistAt the Current Level
Evaluate Adoption StrategiesReferenceHypothetical Feasibility *Additional incentives is a general representation of all types of incentives including potential upfront incentives and performance-based incentives offered by GWP. Assuming receipt of GWP incentives requires customers dispatch battery storage against utility signals to maximize community benefits.

Continue Current NEM
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48 Possible InterpretationsÊEligible systems include customer-sited solar, solar + storage, and/or standalone storage systemsÊAchieve the resolution by December 31st, 2027ÊEligible GWP electric customer adoption includes:1.Rooftop solar owned, financed, or leased by single-family and commercial & industrial customers (one system for one electric customer)2.Rooftop solar owned, financed, or leased by multi-family property owners/managers and commercial & industrial customers under virtual solar programs and shared among tenants and unit owners (one system for multiple electric customers)3.Subscribers of off-site solar solutions like community solar, solar share, and green rate options (one project for numerous electric customers) Possible InterpretationsÊAchieve the resolution by December 31st, 2027ÊEligible demand management measures include solar, storage, electric vehicles, energy efficiency, and/or demand response (both load shedding and load shifting)ÊFocused on additional measures and exclude existing capacity ÊPeak dispatchable capacity: battery storage and EVs with bidirectional charging/discharging capability (V2G)ÊPeak load-reducing capacity: solar, EV managed charging (V1G), energy efficiency, and demand response which either shave load during peak periods or shift load to off-peak periodsÊCapacity measured by nameplate capacity or effective capacity (kW) How we interpret the City Council’s resolution is importantIn August 2022, the Glendale City Council passed a resolution expressing their intent to adopt policies and practices aimed at achieving the goal of having at least 10% of GWP customers adopt solar and energy storage systems by 2027, and to develop additional demand management measures with a minimum total peak dispatchable and peak-load-reducing capacity of 100 MW.At least 10% of GWP customers adopt solar and energy storage systems by 2027 Develop additional demand management measures, with a minimum total peak dispatchable and peak-load-reducing capacity of 100 MW Expanded Eligibility Criteria •In general, Effective Capacity = Nameplate Capacity * ELCC•Effective Load Carrying Capability (ELCC) measures a resource's contribution to reliability based on the incremental quantity of load that can be satisfied by adding the resource to the grid Key Clarification Question: Which systems qualify for the 10% adoption target? Standalone SolarSolar + StorageStandalone Storage
Key Clarification Question: 100 MW nameplate or effective capacity?Nameplate CapacityEffective CapacityVS. 180 of 559

49 ÊProgram proposals ranked by overall qualitative performanceÊReasonable DER compensation levels that mitigate cost shifts are preferred Qualitative screening analysis prioritizes program and policy options crucial for achieving City Council targets over othersPriority Level 181 of 559

Detailed Scenario Analysis
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51 ÊScenarios are shaped by stakeholder inputs, policy directions, and the balancing of multiple GWP objectives.ÊEach proposed program portfolio should be evaluated based on its effectiveness in addressing these values from various perspectives.

The performance of each scenario should be comprehensively evaluated using different metrics to assess adoption, equity, and costs Encouraging Customer Adoption
Realizing Value for Grid & CommunityManaging Cost-Shift & Affordability Balancing Multiple Objectives
AdoptionRatepayer ImpactRate & Bill Impact
Distributional Equity ImpactOthers
Key Scenario Performance Metrics
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52 Adoption scenarios project theoretical upper bounds for adoption, resulting in net ratepayer costs and rate impacts 0%
5%
10%
15%
20%
25%
30%
2024
2025
2026
2027
2028
2029
2030
0%
5%
10%
15%
20%
25%
30%
2024
2025
2026
2027
2028
2029
2030
•The adoption scenarios project upper bounds for solar adoption by 2027. The adoption level results will be further limited by implementation barriers, customer adoption behavior, and other financial and non-economic barriers that customers face.•All proposed strategies impose more costs on GWP ratepayers and lead to further increases in retail rates.•There are alternatives to current NEM that can still promote local solar and storage but also reduce costs to GWP ratepayers.

Reference Scenario (S0)Range of Scenario Results (S1-S4) Solar Adoption (%)Storage Adoption (%)Net Ratepayer Costs ($)Rate Impacts (¢/kWh)CumulativeCumulativeAnnualCompared with rates w/o post-2023 solar and storage Continue Current NEM (S1)
On top of other sources of anticipated rate growthYear
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53 ÊScenarios are shaped by stakeholder input, policy directives, and GWP’s goals. Each scenario’s proposed program portfolio was evaluated based on how effectively it addresses these values from various perspectives.ÊContinuing the current NEM structure may lead to higher costs. However, a strategically planned program and incentive portfolio could drive greater solar and storage adoption, improve distributional equity, and reduce ratepayers' costs.

Metrics of Success by Adoption Scenario
GWP ImpactsDistributional Equity ImpactsSolar Adopter ImpactsNet Economic Societal BenefitMinimize Cost ShiftReduction of GHG ImpactsEase of ImplementationLMI Customer AdoptionIncreased AdoptionAdopter Financial ValueRenter Adoption S1Continue Current NEMS2Targeted LMI MF Adoption
S3Balanced
S4Widespread Adoption
Mid
HighHighHighHigh
Very HighVery High
Very HighLowLowHighHigh
HighHighVery Low
HighHigh
HighHighLowHighHighMidVery Low
Low
Mid
Very Low
Mid
HighHigh
Very High
Societal and Ratepayer Impacts
Low
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Customer Adoption Projections
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55 2027 Customer Adoption by Scenario – SolarIncluding solar-only and solar + storage systems, cumulative adoption by 2027 S1: Continue Current NEMS2: Targeted MF LMI AdoptionS3: BalancedS4: Widespread Adoption LMI: Low and Moderate IncomeMF: Multi-family
10%
12% 12%
16%
2%
5%
4%
6%
1%
5%
5%
8%
1%
6% 5%
8%
0%
2%
4%
6%
8%
10%
12%
14%
16%
18%
S1 S2 S3 S4
Total and LMI Adoption in 2027 Relative to All GWP Customers (%) Total Adoption
LMI Adoption
MF Adoption
Renter Adoption
% of Total GWP Customers

9.6%

11.7% 11.8%

15.8%

1.6%

4.9% 4.4%

6.3%

1.0%

5.1% 4.8%

8.0%

0.9%

5.3% 5.1%

8.2%

0.0%

2.0%

4.0%

6.0%

8.0%

10.0%

12.0%

14.0%

16.0%
S1 S2 S3 S4
Adoption in 2027 Relative to All GWP Customers (%)
Total Adoption
LMI Adoption
MF Adoption
Renter Adoption
% of Total GWP Customers
Adoption Scenarios
Solar Adoption (% of Total GWP Electric Customers)
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56 2027 Customer Adoption by Scenario – Battery StorageIncluding solar + storage systems, cumulative adoption by 2027 LMI: Low and Moderate IncomeMF: Multi-family

1.5%

2.7% 2.1% 2.0%

0.3%

1.4% 1.1% 1.0%

0.2%

1.5% 1.2% 1.4%

0.3%

1.5% 1.2% 1.4%

0.0%

2.0%

4.0%

6.0%

8.0%

10.0%

12.0%

14.0%

16.0%
S1 S2 S3 S4
Adoption in 2027 Relative to All GWP Customers (%)
Total Adoption
LMI Adoption
MF Adoption
Renter Adoption
% of Total GWP Customers

1.5%

2.7%

2.1% 2.0%

0.3%

1.4% 1.1% 1.0%

0.2%

1.5% 1.2% 1.4%

0.3%

1.5% 1.2% 1.4%

0.0%

2.0%

4.0%

6.0%

8.0%

10.0%

12.0%

14.0%

16.0%
S1 S2 S3 S4
Adoption in 2027 Relative to All GWP Customers (%)
Total Adoption
LMI Adoption
MF Adoption
Renter Adoption
% of Total GWP Customers
S1: Continue Current NEMS2: Targeted MF LMI AdoptionS3: BalancedS4: Widespread AdoptionAdoption Scenarios Battery Storage Adoption (% of Total GWP Electric Customers) 188 of 559

57 Strategically planned program and incentive portfolios could achieve higher solar and storage adoption with lower impacts on GWP ratepayers $0.0
$0.1
$0.2
$0.3
$0.4
$0.5
0%
2%
4%
6%
8%
10%
12%
14%
16%
S0 S1 S2 S3 S4
$/W-yr
% of GWP Electric Customers
2027 Solar Adoption (%)
2027 Storage Adoption (%)
2024-2027 Program Cost Indicator ($/W-yr)
The 2024-2027 Program Cost Indicator ($/W-yr) is calculated as:

NEM CompensationAdditional IncentivesAccess for Renter and LMI CustomersProvide More Utility Support Program & Incentive Design
Address Additional Barriers
Adoption Scenarios
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Economic Analysis: Scenario Comparison
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59 ÊThe CPUC defines “cost-effective” and “cost-effectiveness” as a set of well-defined “cost tests in the California Standard Practice Manual (SPM)”*ÊThese cost tests provide a methodological framework to examine the benefits and costs of a particular measure from different perspectives and have become a standard in many other jurisdictions Cost-Effectiveness and Cost Test Perspectives
Cost Test Primary QuestionPCTParticipant Cost TestNet benefit for customers who adopt solar?RIMRatepayer Impact MeasureWill utility rates increase or decrease?PACTProgram Administrator Cost TestWill utility costs increase or decrease?TRCTotal Resource Cost TestNet benefits to City of Glendale?SCTSocietal Cost TestNet benefit to society as a whole?* California Standard Practice Manual 191 of 559

60 Benefits and Costs Components by Cost Test Perspective ComponentParticipant Cost Test (PCT)Ratepayer Impact Measure (RIM)Societal Cost Test (SCT)Bill Savings+–Upfront Costs– –Fixed Operations and Maintenance Costs– –Federal and State Incentives+ +GWP Incentives+–Utility Avoided Costs++Resiliency Benefits+Additional Societal Benefits + N/ACostBenefitNote: Administrative costs were not included in the cost tests. When interpreting the results, please consider these additional costs from both the ratepayer and administrator perspectives to ensure that all program implementation expenses are fully accounted for.

Encouraging Customer Adoption
Realizing Value for Grid & CommunityManaging Cost-Shift & Affordability Participant Cost Test
Ratepayer Cost TestSocietal Cost Test
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61 Economic Analysis of Scenarios: Cost Test Scores
S1Continue Current NEMS2Targeted LMI/MF AdoptionS3BalancedS4Widespread Adoption Participant Cost Test

2.252.163.04

3.04 Ratepayer Impact Measure

0.280.450.390.29
Societal Cost Test

1.872.092.112.17
𝐵𝑒𝑛𝑒𝑓𝑖𝑡𝑠𝐶𝑜𝑠𝑡𝑠≥1.0
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62 ÊAll scenarios have annual net ratepayer costs that increase GWP rates due to accelerating DER adoptionAnnual Net Ratepayer Costs $-
$20
$40
$60
$80
$100
$120
2024
2026
2028
2030
2032
2034
2036
2038
2040
2042
2044
2046
2048
2050
2052
2054
Millions
S1 Net Ratepayer Costs
S2 Net Ratepayer Costs
S3 Net Ratepayer Costs
S4 Net Ratepayer Costs
$-
$20
$40
$60
$80
$100
$120
2024
2026
2028
2030
2032
2034
2036
2038
2040
2042
2044
2046
2048
2050
2052
2054
Millions
S1 Net Ratepayer Costs
S2 Net Ratepayer Costs
S3 Net Ratepayer Costs
S4 Net Ratepayer Costs
S4
S2S3S1
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63 Key Takeaways: Cost and Benefit AnalysisParticipant Perspective•In all scenarios, solar and solar + storage provide net benefits over the system's lifetime•Net benefits are driven by high bill savings under various billing mechanisms, even under net billing•Despite lifetime savings, high upfront costs of solar and solar + storage may still pose barriers to adoption SocietalPerspective•Solar and solar + storage provide net benefits to society across all scenarios Ratepayer Perspective•All adoption scenarios have net ratepayer costs, meaning compensation provided to solar and solar + storage customers higher than the cost savings for GWP•A strategically planned program and incentive portfolio can achieve higher solar and storage adoption with lower impacts on GWP ratepayers 195 of 559

Findings and Recommendations
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65 Clarifications on how to correctly interpret the City Council’s adoption targets are necessaryAt least 10% of GWP customers adopt solar and energy storage systems by 202710% adoption target for solar + storage systems vs. 10% for either solar or solar + storage systems? Develop additional demand management measures, with a minimum total peak dispatchable and peak-load-reducing capacity of 100 MW Which systems qualify?
Standalone SolarSolar + StorageStandalone Storage
100 MW nameplate or effective capacity?
Nameplate CapacityEffective CapacityVS.
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66 Findings: Achieving the adoption goals by 2027 is not feasibleAchieving a goal of 10% customer solar adoption by 2027 is not feasible. The goal is theoretically feasible by 2030 with a significant increase in utility costs and effort, but real-world barriers remain.Achieving a goal of 10% customer storage adoption in the near future is not feasible. Achieving a goal of 100 MW of reliable peak load reduction with DERs is not feasible.

Industry studies suggest that achievable potential is 20%-40% of the technical potential. 198 of 559

67 Findings: Adoption of customer-owned solar and storage increases GWP rates The scenarios achieving 10% solar adoption would result in a projected net cost of $23-$45 million to GWP ratepayers from 2024 to 2027. §Implement a Net Billing Tariff to reduce the cost shift.§Develop and implement non-bypassable charges and fixed customer charges to reduce the cost shift.§Evaluate the cost and feasibility of changes to GWP’s billing and metering systems needed to implement a Net Billing Tariff.

The resulting rate increase would be 6-11% by 2030, with a low- and moderate-income (LMI) customer monthly bill increase of $4-$6.

Recommendations
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68 Findings: Current customer-owned solar and storage adoption is predominately by single-family homeowners above the median incomeCustomer solar adoption in Glendale to date is above 10% for single-family homes and below 1% for renters and LMI customers.84% of customer solar adoption is in households above the median income. 88% of customer solar adoption is by property owners.
90% of customer solar adoption is in single-family homes. §Allow lower cost community solar and storage to count towards achieving the adoption goal.§Evaluate virtual solar programs that renters and LMI customers can subscribe to.§Evaluate the cost and feasibility of changes to GWP’s billing and metering systems needed to implement virtual solar programs.

Recommendations
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69 Findings: Customer-owned solar and storage provides limited reliable peak capacity reduction §Implement TOU rates that encourage customer storage adoption and dispatch for peak capacity reductions.§Study and expand demand response, electric vehicle, energy efficiency, utility dispatchable DER, and other programs for peak load reductions.§Evaluate the cost and feasibility of changes to GWP’s billing and metering systems needed to implement TOU rates and utility dispatchable DER.

The effective capacity of customer-owned solar is less than 10% of the installed capacity.

70 Findings: Additional costs not included in this study will be required §Evaluate Glendale-specific program elements that will be the most effective for increasing DER adoption by renter, LMI, and DAC customers.§Evaluate the cost and feasibility of necessary changes to GWP’s billing and metering systems.§Consider the cost of additional program overhead and customer outreach.

Recommendations
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71 Options for Program Improvements: Rooftop Solar Compensation Compensation RatesShift solar and storage compensation to a net billing tariff structure.Align export compensation with GWP avoided costs.Require TOU rates for solar and storage program enrollment.

Program Sizing ConstraintsExpand total program size by allowing more customers to be subscribed to the customer generation tariff.Relax constraints on system sizing.

Retail Rate Reform for All CustomersPromote or mandate a switch from flat rates to TOU rates.Consider non-bypassable and fixed charges to minimize cost shifts.Align TOU rate peak and off-peak periods with underlying system costs. 203 of 559

72 Options for Program Improvements: Feed-in-Tariff
Program Sizing ConstraintsExpand total program size beyond 4.2 MW. Remove the 1.4 MW constraint on system sizing.

Long-Term Rate GuaranteesConsider long-term rate guarantees. GWP’s current feed-in-tariff only locks in compensation for a single year, preventing developers from conducting economic analyses over the resource's lifetime.

Location-Specific IncentivesConsider incentivizing the usage of underutilized space for solar, including carports (parking canopies), landfills, and other large flat surfaces. This could be in the form of an adder to the feed-in-tariff or an upfront rebate. 204 of 559

Section 2Introduction
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74 Who is E3? Thought Leadership, Fact Based, Trusted
San FranciscoNew YorkBoston
300+ projects per year across ourdiverse client base
130+ full-time consultantsEngineering, Economics, Mathematics, and Public Policy Degrees30+ years of deep expertise Calgary
Recent Examples of E3 ProjectsE3 ClientsMarket price forecasts for every U.S. market (wholesale and retail), supporting billions of dollars of capital deployment;Buy-side diligence support on several successful investments in electric utilities (~$15B in total);Assessment of east coast and west coast offshore wind opportunities (multiple clients);Hydrogen policy and market support for State of Colorado, Mitsubishi Americas, ACORE, and multiple developer and utility clients; Supporting investment in several stand-alone energy storage platforms and individual assets across North America (15+ GW | ~$5B);Evaluation of electric vehicle and V2G markets in North America for several large automakers;Supporting NYSERDA across Climate Leadership and Community Protection Act topics;Supporting investment in 5+ GW of community solar and distributed energy resource projects;Supporting several electric vehicle infrastructure and automakers with strategy.

Denver
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75 ÊE3 is the largest consulting group focused on the clean energy transition in North AmericaÊE3 is a recognized thought leader on decarbonization and clean energy transition topicsÊE3 has four major practice areas covering energy systems from bulk grid to behind the meter Who is E3?
•Valuation of DERs•DER dispatch and asset optimization•Rate design•Grid modernization•Building electrification•Vehicle electrification •Integrated resource planning for electric systems: reliability and resource mix•Planning for utility and state RPS + GHG targets•Utility planning and procurement decisions DER / Electrification / RatesIntegrated System Planning Economy-wide energy systemsBulk grid power systemsGrid edge & behind-the-meter •Climate and energy policy analysis•Long-term energy & climate scenarios•Electrification and low-carbon fuels •Future of gas Climate Pathways / Policy Analysis
•Asset valuation and due diligence•Strategic advisory•Energy market price forecasting•Market design•Transmission planning Asset Valuation & Strategy
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76 E3’s comprehensive modeling toolkit positions E3 well to study future energy system dynamicsHourly simulations of electric loads for specific end usesDetailed operational simulations of system dispatch and flexibility needsEconomy-wide accounting of energy supplies and demands under deep decarbonization scenarios Loss of load probability simulation to measure resource adequacy RESHAPE & EVGridProduction Simulation(AuroraXMP and PLEXOS)PATHWAYS RECAP
Optimal capacity expansion model for electric systems

RESOLVE
Hour of Day123456789101112131415161718192021222324JanFebMarAprMayJunJulAugSepOctNovDec2018 Loss of Load High LOLP occurs in summer evenings when load is high but solar output declines 2018Loss of Load Probability
Hourly electrification loads during a three-day cold snap Hour of Day
Dynamic operating reserves for renewable integration

RESERVE
Economy-wide energy systemsBulk grid power systemsGrid edge & behind-the-meter Low-Carbon Fuels and Future of Gas
Fuel Cost
Fuel Supply
Role of fuels in deep decarbonizationDER Toolkit for optimizing DER value stacking opportunities and adoption

RESTORE & IDSM
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77 Context & BackgroundÊGlendale has set ambitious clean energy goals to establish itself as a leader in clean energy and is committed to maintaining its position as a leader in local clean and renewable energyÊGrayson Repowering Project & Pursuit of Cleaner Alternatives:•Glendale approved the Grayson Repowering Project, including environmentally superior alternatives.•Project Alternative 7 features five reciprocating internal combustion engines (RICEs) totaling 93 MW and 75 MW/300 MWh energy storage systems.•Glendale seeks cleaner alternatives to minimize the need for RICEs.ÊRooftop Solar and Battery Storage:•Glendale aims to enhance residents' rooftop solar access and encourage additional installations.•Battery storage, located at customer or city sites, will provide significant local clean energy resources.•Glendale recognizes load growth from electrification and seeks to evaluate the co-benefits of solar and storage systems with electrification efforts.ÊDemand Reduction and Load Shifting:•Glendale plans to reduce electricity demand and shift energy use to off-peak hours, enhancing system reliability.

City Council ResolutionÊGlendale intends to:•Maximize the use of clean and renewable energy to serve the community.•Achieve 100% clean energy by 2035.ÊThe Glendale City Council passed a resolution expressing their intent to adopt policies and practices aimed at:•Achieving the goal of having at least 10% of GWP customers adopt solar and energy storage systems by 2027.•Developing additional demand management measures, with a minimum total peak dispatchable and peak-load-reducing capacity of 100 MW.ÊStaff is directed to:•Engage with a consultant to develop the adoption plan.•Calculate the estimated dispatchable capacity and demand reduction.•Determine the benefits and costs of the plan, including direct/indirect economic, environmental, societal, and other non-economic benefits and costs.

Glendale’s City Council resolution outlines its clean energy commitment 209 of 559

78 GWP partnered with E3 to create an equitable solar and energy storage adoption plan with input from the community, focusing on community outreach and ensuring that multifamily and rental properties are thoroughly incorporated into the plan.

79 ÊE3 submitted a proposed budget and scope of work that we felt most cost-effectively met Glendale’s objectives, but did provide all the deliverables requested in the RFP .ÊIn response to input from the community and City Council, proposed work was shifted to increase emphasis on community outreach and the number of stakeholder meetings, with no increase in the overall budget. The shift in scope included:•Reducing the level of effort for program design recommendations•Focusing on solar and storage and not evaluating other DER in depth ÊE3 developed and recommended program options that would help the City achieve its goals in a more cost-effective and equitable manner than net energy metering (NEM) alone.

80 E3’s analytical support focused on several research questions How can local solar and distributed energy resources be effective, economic, and equitable parts of GWP’s reliable, low-carbon resource portfolio? Encouraging Customer Adoption
Realizing Value for Grid & CommunityManaging Cost-Shift & Affordability Balancing Multiple Objectives

81 E3’s project leadership team drew expertise from across the firm with expert support from Willdan and Dakota Communications ADVISORYSUPPORTKEY PERSONNELJun ZhangSr. Mng. ConsultantProject Manager Sierra SpencerManaging ConsultantCost Benefit Lead
Patrick BurgessVice PresidentWilldan DER Lead
Eric CutterPartnerProject Lead
Ben Laboy, PESenior Project Engineer
Fangxing LiuSenior ConsultantDemand Impact Lead
Brendan MahoneySenior ConsultantProject Analyst
Hannah PlatterConsultantProject Analyst
Jonathan BatyAssociate Vice PresidentPrimary Engineer
Max DeLoachMarket Analyst
Rick TaylorPartnerOutreach Support Lead
Jad HagekhalilProject AssistantOutreach Support
Snuller PriceSenior PartnerSenior Advisor
Charlie DuffManaging ConsultantProject Advisor
Lindsay BertrandSr. Mng. ConsultantAsst. Project Manager Tara Katamay-SmithSenior ConsultantProject Advisor
Mike SontagAssociate DirectorProject Advisor
Category 1Category 2Category 3
*Dec 2023*Feb-Mar 2024
Parker WildConsultantProject Analyst
Rosie KangVice President
Arne OlsonSenior PartnerSenior Advisor
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82 Category 2Category 1 & 3
E3 employed an integrated analysis workflow because these categories are inherently interdependent and interactive with each other C1: Technical Potential by Market Segmentation
C2: Optimal Dispatch of DERs
C3: Cost-effectiveness of DERs
PCT

PCT/RIM/TRC/SCT
C1: Adoption Forecast
C3: Cost-benefit Analysis
C2: Unit Dispatchable & Peak-load-reducing Capacity
C2: ELCCs of DERs
C2: Aggregated Dispatchable & Peak-load-reducing Capacity Avoided Costs
Other Benefits
Building, Demographic, Socioeconomic, & Customer Data
Customer Load
Retail Rates & Escalators
Avg System Size
System Costs
Federal & State Incentives
Load Escalators
System Characteristics
Financing Assumptions
Historical Adoption
Adoption Parameters
Mandated Adoption
GWP Inputs:System LOLHs
C1: Programs & Incentives Recommendation
Community Inputs
E3 Research & Expertise
•Multiple scenarios from 2024 to 2030
Input Data
Tasks
C3: Develop Avoided Costs & Other Benefits
GWP Inputs

PV, BESS

PV, BESS
ELCCs and adoption forecasts for EE, DR, EV and other flexible loads will be based on GWP IRP or other public data sources.

PV, BESS

PV, BESS
EV, DR

PV, BESS
Feedback & Iterations
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83 Turning potential into adoption requires a multifaceted approach to ensure equitable solar and DER adoption in Glendale Community Outreach
Permitting, Interconnection, and Approval Rules & Process Program & Incentive Design
Equity Strategies
Additional DR, EV, and EE Strategies
Utilize modeling and scenario analysis to evaluate and identify effective, least-cost, and equitable strategies, along with improved and customized avoided cost valuation and cost-benefit analysis for GWP These are the prerequisites for encouraging more adoption – incorporate community inputs and E3/Willdan project experience and expertise Energy Efficiency
Customer-Sited SolarEnergy Storage
Electric Vehicles
Flexible LoadsDemand Response
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84 Turning potential into adoption requires a multifaceted approach to ensure equitable solar and DER adoption in Glendale Community Outreach
Permitting, Interconnection, and Approval Rules & Process Program & Incentive Design
Equity Strategy
Demand Response, Electric Vehicles, and Energy Efficiency Utilize modeling and scenario analysis to evaluate and identify effective, least-cost, and equitable strategies, along with improved and customized avoided cost valuation and cost-benefit analysis for GWP .

85 E3 designed the following workflow to support the adoption plan development Estimation of DER potential from all market segments
Enhancement of avoided costs to reflect GWP system plans and characteristics Analysis of adoption scenarios to identify the feasibility of City Council targets and short-list the most promising and effective policy and program options Benefit cost analysis considering direct/indirect economic and non-energy benefits; outline cost and benefit implications of all possible adoption strategies and alternatives to inform GWP’s decision-making process Deep dive into program options to provide program recommendations that balance customer adoption, customer affordability, and achieving value for the whole Glendale community 217 of 559

Section 3Community Outreach & Engagement
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87 GWP held five community meetings to gather input and feedback, and to share information with the communityStakeholder Participation• Following a resolution by the Glendale City Council, GWP established new goals for solar and energy storage installations, aligning with clean energy targets.•To achieve and analyze the feasibility of these goals, GWP contracted E3 to lead research and analysis efforts, with the goal of presenting an adoption plan to the Glendale City Council in September 2024. •E3 and GWP prioritized engaging renters, multi-family homes, low-income customers, and pollution-burdened customers in their research and creation of adoption scenarios. •E3 and GWP hosted a total of five community meetings, four in person and one virtual, to provide stakeholders with an overview of Glendale's solar and energy landscape and gather direct feedback from the community. •The first three meetings introduced key energy concepts and solicited initial feedback, while the last two meetings presented preliminary research findings and potential solar and DER adoption scenarios.

StakeholderOutreach• GWP made extensive efforts to inform residents and businesses about the community meetings through multiple channels.•These included two bill inserts in customers’ bi-monthly bills, direct mail reminders, a dedicated webpage, press releases, social media posts, email blasts, and a text message blast to over 40,000 GWP customers.•Additionally, an online survey with over 20 questions was distributed to gather input from those unable to attend the meetings.•The survey received over 100 detailed responses, helping E3 and GWP understand customer priorities for the solar and energy storage plan.

Community Meeting Participation• GWP and its consultants held a total of five community meetings to increase attendee knowledge on solar and energy storage in Glendale, discuss the resolution's benefits and challenges, and gather feedback.•Each meeting included a presentation followed by discussions at four key topic stations. The meetings concluded with a Q&A session and an invitation for attendees to submit comment cards.•The first two meetings were held in person, with over 50 and 40 attendees respectively, while the third meeting, a Zoom Webinar, had over 70 attendees, making it the most attended.•The last two meetings, which focused on presenting preliminary research findings and potential adoption scenarios, featured an extended Q&A session instead of discussion stations.•Feedback from the meetings led to a streamlined presentation emphasizing clear graphics and key points.•PDF versions of the presentations for all five meetings are available on GWP’s Solar and Energy Storage Plan’s dedicated webpage. •Press coverage of the third community meeting: •https://glendalenewspress.outlooknewspapers.com/2024/03/18/glendale-water-and-power-talks-highlight-solar-panel-costs-permits 219 of 559

88 ÊMeetings 1-3 took place before the plan design phase of the project, with the goal of informing residents on the project, and gathering feedback to incorporate into the plan design phase.

ÊMeetings 4-5 took place during the plan design phase of the project, with the goal of providing information and progress about the plan, gather feedback, and understand other areas of concern from the community.

GWP held five community meetings to gather input and feedback, and to share information with the communityMeeting 1Meeting 2Meeting 3Meeting 4Meeting 5Wednesday, February 28thSaturday,March 2nd Monday,March 11th Wednesday, May 15thThursday, May 30th Adult Recreation Center201 E Colorado St, Glendale, CA 91205 Sparr Heights Community Center1613 Glencoe Way, Glendale, CA 91208 Zoom/Webinar
Adult Recreation Center201 E Colorado St, Glendale, CA 91205 Sparr Heights Community Center1613 Glencoe Way, Glendale, CA 912086:00 – 8:00 PM10:00 AM – 12:00 PM6:00 – 8:00 PM6:00 – 8:00 PM6:00 – 8:00 PMIn-PersonIn-PersonZoom/WebinarIn-PersonIn-Person 220 of 559

89 Environmental Justices & EquityUnderstanding Barriers to DER Adoption Community Meetings 1-3: community input collections via discussion stations and interactive discussionsInfographics were developed to better inform residents and collect their input 221 of 559

90 C&I Customers Plays a Vital Role in DER AdoptionAffordability and Cost Shifts Community Meetings 1-3: community input collections via discussion stations and interactive discussionsInfographics were developed to better inform residents and collect their input 222 of 559

91 Community meetings had great turnout and local press coverage Community Meeting #5Community Meeting #1Glendale Local Press Coverage Presenter: Jun ZhangPresenter: Eric Cutter
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92 Collecting Community Input•Online survey respondent priorities:✚ Affordability and reliability✚Community solar projects to assist renters and low-income households✚Rebates, net metering, and bill transparency✚More education and outreach✚Regulatory and approval process clarity • 40,000 customers surveyed• 100+ unique responses received 224 of 559

93 Collecting Community Input•Comment Cards•Emails•In-Person Notes ✚Upfront rebates for mitigating initial costs✚Net metering for solar and storage✚Expeditedand streamlined approval process✚More guidance on federal and state resources✚More guidance and support in solar and DER adoption process 225 of 559

94 Addressing Community Input•Solar & battery storage contractors on GWP website•Number of installations completedwww.glendaleca.gov/SolarContractors 226 of 559

Section 4DER Technical Potential and Market Segmentation in Glendale 227 of 559

Section 4.1Overview
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97 Parking Lots
Landfill
Industrial
Municipal
High Desert
Agricultural
Scrubland
Multiple types of solar and storage installations are available for GWP , with different cost implications Customer-OwnedCommunityUtility- Scale
Residential
Commercial
Rooftop
Community
Utility-Scale
Achieving City Council’s 10% Customer Adoption Goal
Lower-Cost Alternatives with Similar Environmental Benefits $/kW System Cost
•Hillside solar is not considered by GWP.•Community solar in practice can involve large rooftop installations as well. 229 of 559

98 ÊRooftop Solar: 313 MWÊParking Canopy Solar: approx. 300 MWÊGround-Mounted Solar: approx. 27 MW Technical Potential of Rooftop, Parking Canopy, and Ground-Mounted Solar in the City of Glendale Rooftop Solar: 313Parking Canopy Solar: 300Ground-Mounted Solar: 27 Technical potential is a metric that quantifies the maximum generation or capacity available for a technology in a given region and does not consider the economic or market viability.Variations in the definition of technical potential and assumptions in filtering criteria may impact results substantially.

Rooftop solar technical potential for the entire City of Glendale, including city-owned properties 230 of 559

99 ÊGWP conducted site-specific analyses on over 100 city-owned properties for potential large-scale rooftop, parking canopy, and ground-mounted solar projects•Over 60 sites are deemed feasibleÊMost sites are filtered out due to their project size of less than 100 kW each and various other developmental constraints, for example:•Not solar ready•Solar not advised by property owners•Historical or community use•Pending roof, structural, reconstruction, ADA, and feeder upgradesÊGWP has identified 10-15 large city-owned sites for developing solar projects•Collectively 10 MW of solar capacity•Six projects approved for construction (5 MW) Achievable solar and storage potential for city-owned properties must account for additional real-world constraintsTechnical Potential of Rooftop, Parking Lot, and Ground-Mounted SolarTotal Analyzed16 MWSolar Ready10 MW 5 MW
•Additional sites evaluated after the initial round of solar site analysis were not included. 6 Sites
10-15 Sites
100+ Sites
Approved for Construction
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Section 4.2Parking Canopy & Ground-Mounted Solar
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101
ÊE3 identified the boundary of non-residential parking lots 5,000 sq. ft. or greater within the City of Glendale, including city-owned parking lots•Used LARIAC orthogonal imagery* from 2014, similar to NREL’s LA100 study, and included paved areas on C&I and government properties (excluding sidewalks, structures, landscaping, etc.)ÊAssuming 125 W/m2 of parking lot area (approximately 11.6 W/ft²), E3 identified sites capable of siting a solar canopy of 100 kW or more. •Approximately 3.5 kW/parking space accounts for partial coverage and CA laws prohibiting construction over rights-of-way•Minimum system size derived from E3’s experience working with GWP and many other developers of commercial-scale, front-of-the-meter systemsÊSites meeting this criteria were included in the estimate of parking canopy technical potential, which totals approximately 300 MW.•Approximately 1,000 paved parking lots sites totaling 2.42 km2 (3% of Glendale’s city area, approximately 26 million sq. ft.) Technical Potential Methodology - Parking Canopy Solar
Paved lots within Glendale suitable for parking canopy solar projects *For more information about the GIS data, please visit: https://egis-lacounty.hub.arcgis.com/datasets/lacounty::parking-lots-2014-from-lariac/about City LimitParking Lots
Parking canopy solar technical potential refers to the maximum generation capacity that can be sited on developable parking lot canopies in a region assuming economics and grid integration are not a constraint. Variations in the definition of technical potential may impact results substantially. 233 of 559

102
ÊE3’s analysis leverages a dataset of candidate project areas identified for a recent study that estimates urban ground-mounted solar resource potential in the western United States (Wu et. al., 2023*)•Encompass residential, commercial, and other non-residential urban land uses•Locations with imperviousness >= 1% (i.e., buildings, roads, parking lots, etc.), parks and landmarks, wetlands, bodies of water, and forested areas were excluded•Without additional constraints, more than 870 MW of technical potential exists within the City of Glendale, mostly located in the Verdugo Mountains•Applied additional filters:•Limited terrain slope to less than 18% (~10 degrees), as this is more likely to be developed•Excluded protected areas (PAD-US 4.0), as these areas have existing restrictions on energy developmentÊSites capable of supporting >= 100 kW of ground-mounted solar were included in the estimate of technical potential, which amounts to nearly 27 MW, primarily in the Scholl Canyon landfill•Totaling 0.56 km2 (0.7% of Glendale’s city area, approximately 6 million sq. ft.) Technical Potential Methodology - Ground-Mounted Solar
Ground-mounted solar technical potential with basic exclusions (i.e., prior to the application of slope constraint, 100 kW minimum project size, etc.) shown in blueSites satisfying all siting criteria shown in orange (see below) The majority of technical potential is located in the Scholl Canyon landfill Ground-mounted solar technical potential refers to the maximum generation capacity that can be sited on developable lands in a region assuming economics and grid integration are not a constraint. Variations in the definition of technical potential may impact results substantially. * Wu, Grace, et al. “Minimizing Habitat Conflicts in Meeting Net-Zero Energy Targets in the Western United States.” Proceedings of the National Academy of Sciences 120, no. 4 (January 19, 2023). https://doi.org/10.1073/pnas.2204098120. 234 of 559

Section 4.3 Rooftop Solar & Customer Battery Storage
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104
ÊHigher income customers tend to adopt larger systems. •California residents tend to install smaller systems than other states, with median sizes ranging from 5.6-7.2 kW-DC across income levels.

Understanding the demographics of residential adopters in California provides crucial context for shaping GWP’s future in solar and storage Source: Lawrence Berkeley National Laboratory
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105
Glendale's solar adopters have higher incomes than the county, state, and national averagesLBNL Income Demographics of GWP Solar Adopters: Raw Income, Area Median Income 18%*
* General pop. data (includes non-adopters) is less granular, so households with incomes > $200k are shown in green/blue Share of 2016-2022 Solar Adopters by IncomeShare of 2016-2022 Solar Adopters by County Area Median Income (AMI) Source: Lawrence Berkeley National Laboratory (LBNL)
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106
ÊGlendale has 2,900 customer-sited solar systems totaling 28 MW, most of which are owner-occupied, single-family, non-LMI households. Solar penetration is currently at 3.25% and solar system installations in Glendale have been increasing every year, despite the end of the solar incentive program in 2022.

Glendale’s current solar and storage penetration pattern skews towards single-family, owner-occupied, and non-LMI households

0.0% 2.0% 4.0% 6.0% 8.0% 10.0%12.0%
SF
C&I
MF
Historical Solar Penetration (%)
Customer Sector

0.0% 2.0% 4.0% 6.0% 8.0% 10.0%
Own
Re ntOwnership

107
ÊGlendale has less than 200 customer-sited storage systems, totaling 3 MWh. Most of these systems are owner-occupied, single-family, non-LMI households, with just one large system from commercial customers and none from multi-family residences, reflecting adoption barriers for renter and LMI customers.

Glendale’s current solar and storage penetration pattern skews towards single-family, owner-occupied, and non-LMI households

0.0% 0.2% 0.4% 0.6% 0.8% 1.0%
C&I
MF
SF
Customer Sector

0.0% 0.1% 0.2% 0.3% 0.4% 0.5% 0.6%
Own
Re ntOwnership

108
ÊREPLICA estimates that the City of Glendale has approx. 330 MW rooftop solar potential from residential sector, including single-family and multi-family customers•Owner-occupied, single-family (SF) households have the highest potential, followed by multi-family (MF) rental properties•Difficult to penetrate rental properties because of inherent challenges associated with ownership and split incentives•Resolving these challenges would help unlock over 70% of potential in GlendaleÊExisting Caveats•REPLICA relies on data from 2015, with just 70k households in Glendale. To compare against E3 estimates, E3 scaled REPLICA totals to match current GWP residential customers (approximately 77k total residential customers).•Of the 70k households modeled in REPLICA, 40k are SF and 30k are MF . This breakdown does not perfectly align with the real-world distribution in Glendale as of FY23 (24k SF vs. 53k MF)•REPLICA does not constrain system size based on the customer’s annual load, so E3 ran an unconstrained case for an apples-to-apples comparison Residential Rooftop Solar Technical Potential in GlendaleFrom NREL REPLICA (see appendix for more details) Historical solar adoption is highest among high-income, owner-occupied, single-family households 240 of 559

109
ÊBased on data provided by GWP and other public sources, E3 estimates of rooftop solar technical potential in Glendale are:•Single-Family: 135-269 MW•Multi-family: 108-216 MW•Commercial & Industrial: 188-377 MWÊWide range of sensitivities capture:•Percentage of total roof space available for siting solar (50%, 75%, 100%)•Minimum size and site suitability limitsÊAt this step, system size limits based on the annual load requirement (as specified by the current NEM policy) are not considered•This will be addressed in subsequent analyses to finalize the technical potential in compliance with the rulesÊDoes not include solar potential from private parking lots (carports and canopies), hillside, or landfills Rooftop Solar Technical Potential in GlendaleE3 Estimates vs. NREL REPLICA - 50 100 150 200 250 300 350 400
Single-FamilyMulti-FamilyCommercial &Industrial
Rooftop Solar Technical Potential in Glendale
LowMidHighNREL REPLICA
E3 estimates are based on utility data, compared with NREL REPLICA, in MW * REPLICA data adjusted to account for growth in building stock since publication 241 of 559

110
Rooftop solar technical potential refers to the maximum generation capacity that can be sited on developable rooftops in a region assuming economics and grid integration are not a constraint. Variations in the definition of technical potential may impact results substantially.

Rooftop solar technical potential for planning purposes should further consider system size limits beyond suitability and developable roof areas Project Sunroof

NREL REPLICA
E3
https://sunroof.withgoogle.com/data-explorer/place/ChIJqYPwyDLAwoARpibJ_p6hP-U/https://www.nrel.gov/docs/fy18osti/70901.pdf 466 MW-DC solar installation potential from all sectors, with 80% buildings suitable for solar•Potential estimate includes existing systems•Technical potential is estimated using a machine learning algorithm based on Google’s overhead imagery and weather data•Solar-suitable buildings are identified based on irradiance, orientation, and shading•System size (2 - 1000 kW) is a function of developable roof area, which takes obstacles into account •Does not consider parking lots or fields as eligible sites•Does not limit system size based on applicable program limits (e.g., NEM) 330 MW-DC solar installation potential from residential sector•Potential estimate includes existing systems.•Technical potential is estimated using a statistical model that leverages LiDAR data to determine rooftop suitability•Solar-suitable buildings are identified based on irradiance, orientation, and shading. •System size (> 1.5 kW) is a function of developable roof area, which takes obstacles into account •Does not consider parking lots or fields as eligible sites•Does not limit system size based on applicable program limits (e.g., NEM) 313 MW-DC solar installation potential from all sectors•Potential estimate includes existing systems•Technical potential is estimated using anonymous GWP customer and building data and LA County Assessor parcel data•Developable roof area derived from building footprint with derating factor to account for setback requirements, obstacles, etc.•Glendale solar suitability adjustment of 79.25% (Project Sunroof) to account for structural stability, electrical code compliance, etc.•Any building with enough developable roof area to site a 1 kW system (based on historical installations) is considered solar-suitable •Does not consider parking lots or fields as eligible sites•Runs sensitivities for different rooftop area availability and program limits•Constrains system size based on applicable program limits (e.g., NEM) 242 of 559

111
System Size Limit(% of Annual Load)Developable Roof Area (% of Total Roof Area Available) Site suitability, developable roof areas, system size limits, and other constraints shape rooftop solar technical potential Low
Mid
High
50%
75%
100%
110%
110%
110%
Site Suitability(% of Total Building)

79.25%Low
Mid
High
Final E3 Estimates
Technical potential was estimated using anonymous GWP customer and building data and L A County Assessor parcel data. The study calculated roof area for all suitable buildings, then applied developable roof area, system size, site suitability, minimum project size, and other constraints to develop a range of reasonable estimates of rooftop solar technical potential in the City of Glendale.

Minimum Size(kW for Each Rooftop Solar Installation)1 kW 243 of 559

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ÊObtained anonymous GWP customer and building dataÊFiltered invalid customer accounts (see next page for details)•Excluded government-owned properties and parking lots, accounts without a structure, etc.•Solar suitability adjustment (see right) accounted for structures deemed incapable of supporting rooftop solarÊMerged with parcel data from LA County Assessor •Defaulted to building square footage from tax parcel data due to inconsistencies in customer data•Obtained number of stories from property use code, if available, otherwise estimated based on sector and number of unitsÊCalculated roof area for suitable buildings•Estimated building square footage where missing based on average energy use intensity of accounts with the same meter bill code•Calculated building footprint from square footage and number of stories, then translated to roof area (assuming 0% roof slope)ÊAdjusted roof area based on uniform developable roof area factor of 75% (% of total roof areas available, from LA100 study)•Percentage will vary roof-to-roof based on geometry, but designed to capture 3-foot setback factor required by CA fire code•Obstructions and shading are not explicitly modeled due to the lack of satellite or LiDAR data ÊLimit rooftop solar technical potential based on:•Developable roof area, assuming default power density of 160 W/m2 (approximately 14.86 W/sq. ft., in alignment with NREL REPLICA)•Percentage of customer’s annual load (default to 110% based on GWP’s current NEM program eligibility), assuming DC capacity factor of 20%ÊEnforced minimum size threshold of 1 kW for rooftop solar installations•Based on literature review and analysis of current system sizes in Glendale (where 99.9% of installations are >1 kW historically)ÊDetermined customer battery storage technical potential based on maximum DER ratings allowed by GWP•Assumed only customers with non-zero solar technical potential are considered eligible to install a battery storage system•Minimum storage technical potential is 30 kWh; if solar technical potential exceeds 10 kW, storage technical potential is set to max of 30 kWh or 110% historical average daily usageÊAdditional solar suitability adjustment of 79.25% (based on Project Sunroof data)•Designed to account for factors such as structural stability of roof and electrical code compliance, which cannot be captured solely by customer data Technical Potential Methodology - Rooftop Solar & Customer Battery Storage (E3 Mid-Case) 244 of 559

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ÊSummary of customer accounts dropped from the technical potential analysis:•Info-only meters: 2,554•Public account holders (e.g., Glendale City): 547•City-owned parking lots: 43•No facility (e.g., vacant lots): 808•Other (e.g., cable and telephone boxes, irrigation systems, outdoor advertising, etc.): 85ÊDuplicated identifiers (i.e., combined account ID, customer ID, and service point ID)•Used most recent descriptors (e.g., meter bill code) and summed the annual energy usage across accounts ÊMerged with LA County Assessor tax parcel data•Public data source that contains detailed property use types and building characteristics, such as number of stories and square footage•Merge occurred at the property level (not unit level) with a success rate of ~73%ÊTreatment of missing data•Categorical variables assigned based on most frequent value associated with similar accounts (e.g., sector)•Missing building square footage data (~ 8%) back-calculated using the average energy use intensity of accounts with the same meter bill code Technical Potential Methodology - Rooftop Solar & Customer Battery Storage (E3 Mid-Case) (Continued) 245 of 559

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Ê75% of total roof space (based on building footprint) is considered developable for rooftop solar•Accounts for setback factor required by LA County, as well as potential obstructions; based on research conducted for NREL’s LA100 studyÊSolar potential based on 110% of customer’s annual load•Assuming 20% capacity factor (DC), based on default system parameters from NREL’s PVWatts tool for Glendale•Module power density of 160 W/m2 (approximately 14.86 W/sq. ft.), in line with NREL REPLICA estimate for flat roofs ÊNumber of buildings suitable for solar adjusted to 79.25%•Based on Project Sunroof data for Glendale; accounts for factors such as structural stability of roof and electrical code complianceÊStorage potential aligns with maximum DER ratings allowed by GWP for solar and storage systems•Assume only customers with non-zero solar technical potential are considered eligible to install storage•Minimum storage potential is 30 kWh; if solar potential exceeds 10 kW, maximum storage potential of 110% of the historical average daily usage Rooftop Solar and Customer Battery Storage Technical Potential in Glendale (E3 Mid-Case) Note: These figures represent the theoretical maximum of solar and storage capacity under applicable policies and other constraints. In the adoption analysis, systems were sized based on customer needs. 95 MW30%5 kWdc/cust
86 MW27%2 kWdc/cust
132 MW42%18 kWdc/cust
For Mid-Case
Rooftop Solar Potential in Glendale
559 MWh63%29 kWh/cust
216 MWh24%4 kWh/cust
115 MWh13%15 kWh/cust For Mid-Case
Battery Storage Potential in Glendale
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Solar and Storage Technical Potential Capacity by Customer SectorTotal # of Units# of Solar-Suitable UnitsTotal PV Capacity (MW)Total Battery Storage Capacity (MWh)Total Battery Dispatch Capacity (MW)Single-Family23,84319,04695559279Multi-Family61,20149,13086216108Commercial & Industrial9,4747,49113211557 * Statistics for solar-suitable buildings under E3 “mid-case.” Omits sites that could not be categorized.

Total # of Units# of Solar-Suitable UnitsTotal PV Capacity (MW)Total Battery Storage Capacity (MWh)Total Battery Dispatch Capacity (MW)Owner31,90425,355176550275Tenant62,58850,299137339169Manager26140.050.390.20 247 of 559

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Single-FamilyMulti-FamilyCommercial & Industrial
For Mid-Case, in MWSolar Potential by Sector, Ownership Status, and Building Type E3 estimates identify 313 MW GWP solar potential from all market segments (E3 Mid-Case) * Omits sites that could not be categorized
Key Observations•Single-Family: Owner-occupied single-family residences show the greatest potential for adoption. •Multi-Family: Multi-family rental properties follow closely behind but face challenges due to ownership dynamics and split incentives between owners and tenants. Addressing these issues could unlock significant potential. •Commercial & Industrial: While comprising fewer customers, these sectors have larger average installation sizes, making them significant contributors to achieving the 100 MW DER capacity target. 248 of 559

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Single-FamilyMulti-FamilyCommercial & Industrial
For Mid-Case, in MWhStorage Potential by Sector, Ownership Status, and Building Type E3 estimates identify 900 MWh GWP storage potential from all market segments (E3 Mid-Case) * Omits sites that could not be categorized
Key Observations•Single-Family: Owner-occupied single-family residences show the greatest potential for adoption. Customers with less than 10 kW solar systems can install up to 30 kWh battery storage systems.•Multi-Family: Multi-family rental properties follow closely behind but face challenges due to ownership dynamics and split incentives between owners and tenants. Addressing these issues could unlock significant potential.•Commercial & Industrial: For large solar systems (>10 kW), maximum storage potential is up to 110% of the historical average daily usage, which constrains the potential from the C&I sectors. 249 of 559

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Technical Potential Characteristics of GWP Customers – Rooftop Solar and Customer Battery Storage (E3 Mid-Case)SectorTotal # of Units# of Solar-Suitable UnitsAvg Building Area (sq ft/unit)Avg Roof Area (sq ft/unit)Avg Developable Roof Area (sq ft/unit) Avg Annual Energy Usage (kWh/unit)Avg PV Capacity (kW/unit)Avg Battery Storage Capacity (kWh/unit) Avg Battery Dispatch Capacity (kW/unit)Total PV Capacity (MW)Total Battery Storage Capacity (MWh) Total Battery Dispatch Capacity (MW)SectorSingle-Family 23843190461904.42958.42718.818133.934.9829.3314.6794.90558.68279.34Multi-Family 6120149130947.93296.77222.583614.011.754.402.2085.94216.36108.18Commercial & Industrial947474915409.713408.822556.6151322.7417.5915.297.64131.77114.5157.25Building TypeSingle-Family (1 Unit)22953183441939.85970.23727.678329.345.1030.0015.0093.58550.32275.16Single-Family (2+ Units)890703979.28650.13487.603031.491.8811.905.951.328.364.18Multi-Family (Condo)7986011540.80536.06402.0513263.723.7030.0015.002.2218.039.01Multi-Family (2 Units)36042738969.83658.04493.533594.422.0815.007.505.7041.0820.54Multi-Family (3-4 Units)982876601119.06465.37349.033731.341.518.504.2511.5465.1132.56Multi-Family (5-9 Units)1524112283886.70288.45216.342961.981.794.482.2421.9555.0827.54Multi-Family (10-19 Units)122949947865.12234.31175.732925.651.772.241.1217.5722.3211.16Multi-Family (20-49 Units)117359589903.93205.66154.243565.031.881.100.5518.0010.595.29Multi-Family (50+ Units)77016313990.79165.73124.304989.241.420.660.338.964.152.08Commercial & Industrial (Small)505538944059.253113.762335.3215483.018.0616.118.0631.3962.7531.37Commercial & Industrial (Medium)215717438542.905189.233891.9282621.4432.3216.748.3756.3229.1714.58Commercial & Industrial (Large)226218545300.762355.031766.2797166.0823.7612.196.0944.0622.6011.30Building VintagePre-War 24287191421379.00698.83524.126086.423.3417.568.7863.93336.04168.02Post-War 44325355281535.68767.23575.428639.283.9111.625.81138.84412.74206.37Post-1980 23933195011906.86666.83500.129999.203.685.782.8971.79112.7456.37Unknown197314973491.513160.872370.6565804.5025.4218.729.3638.0528.0314.01OwnershipOwner 31904253552360.061220.52915.3916906.846.9421.7110.86175.91550.47275.24Tenant 62588502991262.61545.01408.755729.452.726.733.37136.65338.68169.34Manager 26141583.07807.55605.666260.213.6028.2414.120.050.390.20 * Statistics for solar-suitable buildings under E3 “mid-case.” Omits sites that could not be categorized.

By Sector, Building Type, Vintage, or Ownership
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Technical Potential Characteristics of GWP Customers – Rooftop Solar and Customer Battery Storage (E3 Mid-Case)SectorBuilding TypeOwnershipTotal # of Units# of Solar-Suitable UnitsAvg Building Area (sq ft/unit)Avg Roof Area (sq ft/unit) Avg Developable Roof Area (sq ft/unit)
Avg Annual Energy Usage (kWh/unit)
Avg PV Capacity (kW/unit)
Avg Battery Storage Capacity (kWh/unit)
Avg Battery Dispatch Capacity (kW/unit)
Total PV Capacity (MW)
Total Battery Storage Capacity (MWh)
Total Battery Dispatch Capacity (MW)Single-FamilySingle-Family (1 Unit)Owner18771149912009.321004.81753.618464.935.1930.0015.0077.85449.73224.87Single-FamilySingle-Family (1 Unit)Tenant416733431628.35815.16611.377722.594.6930.0015.0015.69100.2950.15Single-FamilySingle-Family (2+ Units)Owner4393431007.27737.33552.993776.752.3313.136.570.804.502.25Single-FamilySingle-Family (2+ Units)Tenant451360952.64567.10425.332321.871.4510.735.360.523.861.93Multi-FamilyMulti-Family (Condo)Owner3082391550.68527.03395.2710553.463.6530.0015.000.877.163.58Multi-FamilyMulti-Family (Condo)Tenant4873611538.51543.55407.6615101.623.7330.0015.001.3510.825.41Multi-FamilyMulti-Family (2 Units)Owner11208131004.91650.84488.133614.672.1715.007.501.7612.206.10Multi-FamilyMulti-Family (2 Units)Tenant24821923955.11661.29495.973587.512.0515.017.503.9328.8614.43Multi-FamilyMulti-Family (3-4 Units)Owner14671089907.15366.60274.953685.851.688.584.291.839.344.67Multi-FamilyMulti-Family (3-4 Units)Tenant835765711154.17481.73361.303738.881.488.494.249.7055.7827.89Multi-FamilyMulti-Family (5-9 Units)Owner131310531039.96443.09332.313268.542.014.652.322.124.892.45Multi-FamilyMulti-Family (5-9 Units)Tenant1392811229872.33273.95205.462933.231.774.472.2319.8350.1825.09Multi-FamilyMulti-Family (10-19 Units)Owner7546181042.35303.14227.353764.312.292.151.071.411.330.66Multi-FamilyMulti-Family (10-19 Units)Tenant115409329853.37229.75172.312870.081.732.251.1316.1620.9910.50Multi-FamilyMulti-Family (20-49 Units)Owner141111261019.18215.43161.574641.722.051.120.562.311.260.63Multi-FamilyMulti-Family (20-49 Units)Tenant103248463888.61204.36153.273421.841.851.100.5515.699.334.66Multi-FamilyMulti-Family (50+ Units)Owner8036581001.66165.94124.466136.251.600.780.391.050.510.26Multi-FamilyMulti-Family (50+ Units)Tenant68985655989.53165.70124.284855.721.400.640.327.913.641.82Commercial & IndustrialCommercial & Industrial (Small)Owner189414623811.552773.462080.1014439.197.3815.097.5510.7922.0611.03Commercial & IndustrialCommercial & Industrial (Small)Tenant316024314209.213319.062489.3016115.118.4716.728.3620.5940.6620.33Commercial & IndustrialCommercial & Industrial (Medium)Owner149912217505.924727.453545.5978205.9930.3814.347.1737.1117.528.76Commercial & IndustrialCommercial & Industrial (Medium)Tenant65752110972.296271.084703.3192965.8336.8522.3411.1719.2111.655.82Commercial & IndustrialCommercial & Industrial (Large)Owner212517425115.432147.981610.9891469.2821.8111.465.7338.0019.979.99Commercial & IndustrialCommercial & Industrial (Large)Tenant1371128175.385566.664175.00185528.8653.9523.3711.686.062.621.31•Statistics for solar-suitable buildings under E3 “mid-case.” •Omits sites that could not be categorized. No “Manager” ownership status.

By Sector, Building Type, and Ownership (excludes Vintage) 251 of 559

Section 5Dispatchable Capacity and Demand Reduction Capacity 252 of 559

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E3 reviewed GWP’s IRP focusing on load & DER forecasts to ensure accurate system representation and inform study design Today
Inform Study DesignEvaluate Adoption LeversReview IRP Inputs Reviewed IRP Inputs•To properly support GWP’s DER strategy, E3 must comprehensively understand GWP’s system•The E3 team conducted a thorough review of GWP's Integrated Resource Plan (IRP), load and DER adoption forecast•The review included a detailed analysis of GWP's assumptions, methodologies, and data inputs used in the development of the IRP Evaluated Adoption Levers•The IRP review focused on evaluating GWP's resource mix, key upcoming decisions, and levers that may accommodate the adoption of DERs•It also included an evaluation of the approach to determining the reliability of GWP's proposed resource plan•E3 also had a focused review of GWP’s assumptions and methodologies for assessing the potential for DERs and load growth Informed Study Design•The E3 team leveraged its findings to inform other components of this study, including but not limited to the DER reliability analysis, targeted DER adoption strategies, and the cost benefit analysis Key Decision NeededGWP Goal Deadline
DER OpportunityDER Opportunity
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Role of Local Clean Energy Resources
GWP faces many challenges in transitioning to a cleaner grid, and local clean energy resources could provide significant support Glendale's Clean Energy Vision•60% RPS by 2030 (CA regulatory requirement)•100% Clean Energy by 2035 (Glendale goal)Transmission & Land Constraints•Procuring new renewables outside of the City•Procuring new renewables within the CityIntegrated Resource Plan (IRP) Planning Challenges•Integrating renewables, coal retirement, and hydrogen combustion turbine (CT) conversion•Maintaining system reliability Maintaining leadership in clean and renewable energy
Unlocking more local generation
Reducing fossil fuel generation (Grayson Repower, etc.) System Context and Challenges
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Resource adequacy (RA) is increasing in complexity and importance as the grid shifts to low-carbon resources ÊThe transition towards renewables and storage introduces new complexity in resource adequacy planningÊThe concept of planning exclusively for “peak” demand is becoming obsoleteÊInstead, long stretches with low solar and wind output, corresponding with high loads, are the times of most challenging resource adequacy needsÊAs more of one resource is integrated, the net peak hours shift to other times, reducing its capacity value or ELCC Peak load reductions decline with increasing adoption
Effective Load Carrying Capacity (ELCC)•ELCCmeasures a resource's contribution to reliability based on the incremental quantity of load that can be satisfied by adding the resource to the grid•ELCC expresses the capacity contribution of intermittent and energy-limited resources in terms of equivalent “perfect” capacity (capacity that is always available)•For example, if the ELCC of solar is 50%, then an electricity system with 100 MW of solar (i.e., 50 MW of ELCC) would achieve the same reliability as an electricity system with 50 MW of a perfect resource Diminishing Value of Solar ELCCDiminishing Value of 4h Storage ELCC Schlag et. al., "Capacity and Reliability Planning in the Era of Decarbonization: Practical Application of Effective Load Carrying Capability in Resource Adequacy," Energy and Environmental Economics, Inc., August 2020. Available at: https://www.ethree.com/elcc-resource-adequacy/ Peak load reductions decline with increasing adoption
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ÊE3 has resource adequacy experience across California:•CPUC IRP – California-wide ELCC work•CAISO – CAISO DR ELCC work•LADWP – neighbor for GWP•SMUD – another smaller-sized CA utility ÊFor this study, E3 developed GWP-catered approximations of ELCC without having to conduct extensive Loss-of-load Probability (LOLP) modeling E3 leveraged its experience performing RA analyses and used Effective Load Carrying Capacity (ELCC) results from other CA work LADWP
Portland General ElectricNorthwestern Energy
Florida Power & Light
Xcel Energy
Hawaiian Electric Company
El Paso Electric
NV EnergySacramento Municipal Utilities District
States where E3 has provided direct support to utilities, market operators, and/or state agencies to perform RA modeling or develop RA frameworksAreas where E3 has worked with other clients to examine issues related to resource adequacy OPPD
Nova Scotia Power
New Brunswick Power

NYISOPJMCAISO
SRP
LES
PUCT
Black Hills Energy
Oregon PUCPuget Sound Energy

NYSERDA
E3 has worked directly with utilities across North America to study resource adequacy needs 256 of 559

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ÊCustomer adoption forecasts for distributed solar and storage were modeled across scenarios S1-S5.ÊFor electric vehicles (EVs), demand response (DR), and energy efficiency (EE), a single adoption scenario was modeled based on GWP’s IRP .ÊFurther details are available in Section 7: Adoption and Impact Analysis.

E3 calculated the estimated dispatchable capacity and demand reduction that can be achieved through the adoption plan DER Nameplate Capacity
DER Effective Capacity
DER ELCCs
ÊFor example, if solar has an ELCC of 50%, then a system with 100 MW of solar capacity would provide the same reliability as a system with 50 MW of an ideal, always-available resource. In this case, the effective capacity of solar is 50 MW.ÊFurther details are provided in the following slides.

ÊELCC measures a resource’s contribution to grid reliability by quantifying the additional load the system can support. This concept applies to dispatchable and peak-load-reducing DERs as well.ÊE3 developed tailored ELCC approximations for GWP .ÊFurther details are provided in the following slides. 257 of 559

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E3 designed this approach for approximating GWP DER ELCCs based on data availability 2024 DER Shed or Provided Power Potential
GWP DER ELCCs*
Utility-Scale Battery Storage Marginal ELCC CurveFrom 2022 CPUC ACC Capacity Allocation Hours (2024-2030) 2024 DER End-Use Profiles (Normalized)
GWP DER ELCCs*
Loss-of-Load Hours (LOLH)From 2022 CPUC ACC Capacity Allocation Hours (2024-2030) Approximated from 2022 CPUC IRP DR study
Profiles simulated by this study, or approximated from previous E3 work Approximations based on E3’s work in California and across the U.S.

GWP DER ELCCs*
1 2
3 From 2023 CPUC IRP RESOLVE Utility-Scale 4-hr Battery Storage Marginal ELCC Curve (2024-2030) * Post-processed as a range (±5%) based on the calculated value to account for uncertainties that were not fully addressed Loss-of-Load Hours (LOLH)Electric Vehicles
Solar and Energy Storage
Demand Response
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Key Results: Approximations of GWP DER ELCCs in 2027
Electric VehiclesSolarEnergy StorageDemand Response
GWP BTM solar profiles from PVWatts (used across the whole study)GWP BTM storage profiles simulated by this study (used across the whole study) CA LDEV Shed Potential data from E3 2022 CPUC IRP DR studyFrom E3 CAISO DR ELCC study assuming 15 events per year and 1-hr max duration (approximating GWP Power Saving Program)Exceptions:•LDEV VGI: excluded due to its relatively low deployment level projection in the near term•Energy Efficiency: peak saving forecasts are available from the GWP IRP , which are assumed to already account for capacity contributions •LDEV: Light-Duty Electric Vehicle•VGI: Vehicle Grid Integration 0%
Range
ELCC Range (%)
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Can GWP reach 100 MW dispatchable and peak load reduction capacity by 2027?ÊCustomer-owned solar and storage would provide reliable peak load reductions of 10 MW or less by 2027ÊIncluding other DERs such as demand response, managed electric vehicle charging, and energy efficiency could theoretically provide peak load reductions of 20-44 MW by 2027ÊEffective Capacity: requires approximately 200-300 MW customer solar, 40-60 MW customer battery storage, and other DERs by 2027ÊNameplate Capacity: theoretically feasible with significant utility investment, suggest considering a MW nameplate capacity goal and a later target year Achieving 100 MW Additional DER by 2027:
•Achieving 100 MW additional effective capacity, considering DER’s ability to reduce GWP system peak demand, will require 200-300 MW DER nameplate capacity coming online by 2027.•A more realistic target is achieving 100 MW additional DER nameplate capacity with a later target year.

DER Contributions by 2027
DERNameplate Capacity (MW)Approx. ELCC (%)Effective Capacity (MW)Customer Solar39-700-70-5Customer Storage3-1035-451-5LDEV Managed Charging50-5528-3814-21Energy Efficiency0-5100*0-5Residential and C&I DR8-1268-785-9Total MW100-15220-44 * EE capacity here represents ‘peak saving’ forecast from GWP IRP , E3 assumes peak saving already accounts for capacity contributions (i.e. after ELCC adjustment) 260 of 559

Section 6Customized Avoided Costs for GWP
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DERs have the potential to avoid several system costs
Transmission SubstationTransmission LineTransformer
Transformer
Feeder
Feeder
Primary Distribution LineDistribution/ Final Line TransformerSecondary Distribution Line 10,000 Customers
Primary Distribution Line
Some overloads can be managed with low- cost switching
Distribution Substation1,000 Customers10 CustomersCircuitServiceTransmission Solar Plant
Generation100,000 Customers1 Million Customers
Meter
Customer
Customer
1 CustomerCustomer
Service Panel
Primary DistributionSecondary Distribution
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ÊOrigin: 1978 Public Utilities Regulatory Policy Act (PURPA)•Utilities must pay co-generators/qualifying facilities (QF) their ‘avoided costs’–Avoided cost is the incremental cost of electric energy or capacity which, but for the purchase from the QF , a utility would generate itself or purchase from another source–Avoided costs analysis enables the quick evaluation of the costs or benefits of a particular action while avoiding more time-consuming, complex full planning analysis•FERC outlines principles but gives each state the authority to determine its own approaches ÊSeparate from PURPA, many states turned to this concept to value Energy Efficiency and Demand Side Management•The evolving electricity system makes this valuation more complex than it once was Increasing complexity of the electrical system requires a new approach to translate supply-side investments to avoided costs 263 of 559

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Avoided cost must evolve to reflect the value of DER for a low-carbon grid – a new planning paradigmThen NowPlanning TargetsReliabilityReliability and clean energyMarginal Fixed CostsCombined Cycle Gas TurbineCombustion Turbine Wind, solar, and storageMarginal Variable Costs & EmissionsMostly fuel in all hours - highLimited fuel needed for ramping and reliability - low or zero in most hoursHourly VariabilityModest SignificantPolicy GoalsEncourage conservationEncourage electrification Peaking and baseload resources to meet reliability targets Portfolio of resources selected to meet reliability, clean energy, and GHG targets Energy Efficiency Measures
Customer-Sited PV
Load reducing, fixed shape resources
Storage
Transportation Electrification
20°
Building Electrification
Load increasing, flexible shape resources
Supply SideDemand Side
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Principles of Avoided Cost FrameworkMarginal costs represent the costs that the utility avoids by installing a marginal unit of DER relative to the existing/planned portfolio. These costs serve as implicit and explicit price signals to achieve energy, reliability, and climate goals. Marginal Long-TermLong-term costs represent the long-run avoided costs of a DER over its lifetime, aligning with planning expectations for meeting long-term goals.

Technology A gnosticThese costs provide a single, flexible technology agnostic set of avoided costs that can be applied to all types of DERs.Load ReducingLoad ShiftingLoad Increasing 265 of 559

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Translating avoidable system costs to avoided cost componentsEnergy Generation CapacityGreenhouse Gas/RenewableTransmission Capacity Others
Marginal cost to serve one MWh of load in each hour of the year Marginal cost to add one kW of qualifying resource capacity to the systemMarginal cost to reduce one ton of greenhouse gas (GHG) emissions and/or procure one Renewable Energy Credit (REC)Marginal cost to reduce one kW of transmission capacity needed to meet load growthDistribution CapacityMarginal cost to reduce one kW of distribution capacity needed to meet local load growth – true value is highly location-specific Monetized costs associated with losses, methane leakage, ancillary services, and others 266 of 559

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ÊPrinciple: ensure values were customized, defensible, and aligned with GWP's unique system plans and characteristics while avoiding a complete overhaul of avoided costs to save time and resources ÊUsage: avoided costs are used to quantify DER’s benefits to GWP and as part of the Net Energy Billing (NEB) tariff ÊApproach: E3 calculated GWP avoided costs based on the CPUC 2022 Avoided Cost Calculator (2022 ACC) because…•Precedence: GWP has previously used the CPUC ACC to evaluate energy efficiency programs, establishing a precedent.•Versatility: The hourly stream format of the CPUC ACC is adaptable for evaluating various DERs.•Challenges with Alternatives: Estimating proxy utility-scale resources for each DER can be difficult, especially for flexible resources and EVs.

Principles of calculating GWP avoided costs
$0$50$100$150$200$250$300$350
JanFe bMarAprMayJunJulAugSe pOctNovDec
Average Monthly Value of Energy ($/MWh)
Methane LeakageLossesAncillary ServicesDistribution CapacityTransmission CapacityGeneration CapacityEnergyGHG Adder &Re balancingCap and Trade SCE CZ9 Monthly Average Avoided Costs in 20302022 CPUC Avoided Cost Calculator Month
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Common usage of the CPUC Avoided Cost Calculator (ACC) – the basis of GWP's avoided costs ÊEnergy Efficiency and Demand Response Evaluation•Comparing the total cost of new efficiency measures to the marginal cost savings of the utilityÊSelf Generation Incentive Program (SGIP) Energy Storage Evaluation•What ratepayer benefits and GHG reductions are being realized by behind-the-meter (BTM) energy storage?ÊBuilding and Transportation Electrification•Economic and GHG benefits of utility electrification programsÊValue of Solar•Cost-shift to non-participating customers due to compensating BTM solar at the retail rate 72°
ÊThe CPUC Avoided Cost Calculator (ACC) is a simplified representation of the utility-integrated resource plan to answer:•Are Distributed Energy Resources (DER) more cost-effective than supply-side alternatives? ÊRate Setting•The ACC sets export compensation for prosumers 268 of 559

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E3 updated four components tailored to GWP’s systemsComponents2022 ACC MethodologyUpdates for GWPGeneration CapacityAssumed 4-hr storage is the marginal capacity resource and calculated the opportunity cost of deferring the investment by one yearAssumed various capacity resources by year according to the GWP IRP Renewable/GHGEscalated from the 2035 “shadow price” on the carbon constraint in RESOLVE (the IRP’s capacity expansion model) Removed the GHG adder component and added avoided RECs because GWP plans its system according to a Renewable Portfolio Standard and Clean Energy Standard while the CPUC IRP system is mainly driven by GHG reduction goalsTransmission CapacityProvided by Southern California EdisonAssumed zero for GWP because GWP does not anticipate any change in its transmission upgrade regardless of DER adoptionLossesFrom the CPUC IRPUpdated for GWP (7% transmission losses and 7% distribution losses) Energy, Distribution Capacity, Methane Leakage, and Ancillary Services were not updated due to a lack of detailed data. For example, GWP’s IRP does not have hourly energy prices, which made it challenging to update energy avoided costs. 269 of 559

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$0$50$100$150$200$250$300$350$400
JanFe bMarAprMayJunJulAugSe pOctNovDec
Average Monthly Value of Energy ($/MWh)
Methane LeakageLossesAncillary ServicesDistribution CapacityTransmission CapacityGeneration CapacityEnergyGHG Adder & RebalancingCap and Trade $0$50$100$150$200$250$300$350$400
JanFe bMarAprMayJunJulAugSe pOctNovDec
Average Monthly Value of Energy ($/MWh)
Methane LeakageLossesAncillary ServicesDistribution CapacityTransmission CapacityGeneration CapacityEnergyGHG Adder & RebalancingCap and TradeRE C Result: total avoided costs for GWP are similar to the CPUC ACCCPUC 2022 ACCSCE CZ9 2027GWP Customized Avoided Costs2027 * The CPUC ACC is in 2020 calendar year while GWP avoided costs are in 2018 calendar year Added REC and removed GHG Adder & Rebalancing
Updated capacity avoided costs are higher than the CPUC ACC 270 of 559

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Result: total avoided costs for GWP are similar to the CPUC ACC CPUC 2022 ACCSCE CZ9 2027GWP Customized Avoided Costs2027 271 of 559

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ÊThe avoided cost of capacity reflects the net fixed cost of a new resource that would fulfill the capacity needsÊAvoided capacity costs were calculated as a “residual” of a given capacity resource, meant to reflect the fixed cost of a new resource that is not offset by margins from the energy market•Also described as the “missing money”ÊE3 used Real Economic Carrying Charge (RECC) to derive generation capacity avoided costs for 4-hr storage, consistent with the 2022 ACC, with updated resource costs from GWP’s IRP* ÊE3 calculated the Net Cost of New Entry of the re-powering gas plant and new hydrogen power plant, using GWP’s IRP costs Calculation of Generation Capacity Avoided Costs Calculation of Avoided Capacity Cost$/kW-yr Energy + Ancillary Service Revenues
Avoided Generation Capacity Value ($/MW-yr)
Annualized Fixed Resource Costs
Ancillary service: a group of grid services for balancing electricity supply and demand in real-time and ensuring the smooth operation of the grid *For more details of the RECC method, see 2022 ACC documentation (pg. 38) 272 of 559

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ÊCapacity avoided costs were calculated assuming different marginal capacity resources in different years given the planned capacity resources in GWP’s IRP . •2024-2025: re-powering of gas plant•2026-2034: 4-hr storage•2035 onward: hydrogen CTÊAvoided capacity costs in 2024-2026 should technically be zero because GWP is currently building Grayson Repowering and battery storage, which cannot be avoided by DERs.

E3 calculated capacity avoided costs assuming different capacity resources in different years Grayson ICE generatorsHydrogen conversion by 2035
Source: GWP 2024 IRP
Grayson 4-hr storage
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GWP’s avoided capacity costs are higher than the 2022 CPUC ACC due to higher storage costs and hydrogen CT $- $50 $100 $150 $200 $250 $300 $350 $400
2024202520262027202820292030203120322033203420352036203720382039204020412042204320442045 Generation Capacity Avoided Costs ($nominal/effective kW-yr) GWP2022 ACC
GWP capacity avoided costs are low in the near-term because of low cost in gas plant repoweringGWP capacity avoided costs are higher than the 2022 ACC due to higher storage cost assumed in GWP’s IRPGWP capacity avoided costs stay high after 2035 because a hydrogen CT is assumed to be the marginal capacity resource The 2022 ACC assumes 4-hr storage is the marginal capacity resource for all years Year
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ÊE3 calculated avoided REC as the additional revenue needed beyond the energy market to cover levelized costs for new solar resources. ÊLevelized costs for new solar are consistent with the GWP IRP and reflect higher solar PPA prices in the near term. ÊAvoided REC are discounted by the RPS percentage. Given that GWP plans to serve 100% clean energy by 2035, the RPS is assumed to be 100% after 2035.ÊThe avoided REC is ~5$/MWh in the near term due to RPS discounting and increases over time as solar earns fewer energy revenues due to curtailment.

Calculation of Avoided Renewable Energy Credits (REC)Calculation of Avoided REC$/kW-yr Energy
Annualized Fixed Resource Costs of Utility Solar
REC
Avoided REC
Discounted by RPS% Trajectory
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Section 7Adoption and Impact Analysis
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Section 7.1Scenario Design Framework
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Adoption and Impact AnalysisE3 employed the IDSM tool to assess the predicted adoption of distributed solar and storage according to several different scenarios with varying utility incentives and rate designs•The scenarios were evaluated not only on whether they reached the 10% target but also on their ability to distribute the benefits of DERs equitably among more than a dozen different customer segments•Bill savings, avoided costs, emissions, and other operation metrics were calculated in the model The balance between affordability and adoption impact is a careful consideration when selecting program portfolios to ensure equitable growth•IDSM modeling results enabled the E3 team to reveal the feasibility of achieving the 10% adoption target through a strategic combination of robust community outreach, utility incentives, and a rate design that encourages adoption while also mitigating ratepayer impacts 278 of 559

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Possible InterpretationsÊEligible systems include customer-sited solar, solar + storage, and/or standalone storage systemsÊAchieve the resolution by December 31st, 2027ÊEligible GWP electric customer adoption includes:1.Rooftop solar owned, financed, or leased by single-family and commercial & industrial customers (one system for one electric customer)2.Rooftop solar owned, financed, or leased by multi-family property owners/managers and commercial & industrial customers under virtual solar programs and shared among tenants and unit owners (one system for multiple electric customers)3.Subscribers of off-site solar solutions like community solar, solar share, and green rate options (one project for numerous electric customers) Possible InterpretationsÊAchieve the resolution by December 31st, 2027ÊEligible demand management measures include solar, storage, electric vehicles, energy efficiency, and/or demand response (both load shedding and load shifting)ÊFocused on additional measures and exclude existing capacity ÊPeak dispatchable capacity: battery storage and EVs with bidirectional charging/discharging capability (V2G)ÊPeak load-reducing capacity: solar, EV managed charging (V1G), energy efficiency, and demand response which either shave load during peak periods or shift load to off-peak periodsÊCapacity measured by nameplate capacity or effective capacity (kW) How we interpret the City Council’s resolution is importantIn August 2022, the Glendale City Council passed a resolution expressing their intent to adopt policies and practices aimed at achieving the goal of having at least 10% of GWP customers adopt solar and energy storage systems by 2027, and to develop additional demand management measures with a minimum total peak dispatchable and peak-load-reducing capacity of 100 MW.At least 10% of GWP customers adopt solar and energy storage systems by 2027 Develop additional demand management measures, with a minimum total peak dispatchable and peak-load-reducing capacity of 100 MW Expanded Eligibility Criteria •In general, Effective Capacity = Nameplate Capacity * ELCC•Effective Load Carrying Capability (ELCC) measures a resource's contribution to reliability based on the incremental quantity of load that can be satisfied by adding the resource to the grid Key Clarification Question: Which systems qualify for the 10% adoption target? Standalone SolarSolar + StorageStandalone Storage
Key Clarification Question: 100 MW nameplate or effective capacity?Nameplate CapacityEffective CapacityVS. 279 of 559

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ÊProgram proposals ranked by overall qualitative performanceÊReasonable DER compensation levels that mitigate cost shifts are preferred Qualitative screening analysis prioritizes program and policy options crucial for achieving City Council targets over othersPriority Level 280 of 559

Section 7.2Scenario Design Framework
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The adoption scenarios represent theoretical upper bounds of how much adoption we can expectAdoption Level Optimal Adoption Rate in Ideal ConditionsAdoption Rate in Practical Conditions Adoption Impeded by Real-World Constraints
E3 developed best-case scenarios for evaluating the theoretical feasibility of achieving adoption targets.•While E3 aimed to account for consumer decision-making across different customer groups and the split incentive issue for renters, these methods fall short of fully capturing the broad range of financial and non-economic barriers that households face in adopting DERs. The scenarios represent an upper bound of what is possible if these barriers were mitigated.•The study assumes perfect implementation from GWP providing additional utility support and improved access for renter and LMI customers. Other real-world barriers and constraints that naturally exist regarding admin costs, admin resources, pace of program delivery, community participation rate, etc., are not considered.•The Cost and Benefit Analysis section of this report provides a more comprehensive view of costs and benefits, examining direct and indirect economic benefits and costs as well as environmental, societal, and other non-economic benefits and costs.When interpreting these results in a real-world context, several considerations must be made.•The adoption level will be further limited by how much progress GWP can make on providing solutions for renters and LMI customers and for improving community outreach, support, and permitting processes.•Correspondingly, E3 expects utility program costs to be higher because additional incentives must be imposed to fill in the gap of adoption shortfall.

ILLUSTRATIVE
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Scenario 1: Continue NEMScenario 2: Targeted LMI/DACs & MF AdoptionScenario 3: BalancedScenario 4: Widespread Adoption E3 evaluated four program scenarios to identify target feasibility and show trade-offs in adoption, equity, and costsNEM CompensationAdditional IncentivesAccess for Renter and LMI CustomersProvide More Utility Support Program & Incentive Design
Address Additional Barriers•Low and Moderate Income (LMI)•Disadvantaged Communities (DACs)•Multi-family (MF) 283 of 559

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Each scenario features a portfolio of programs, including some combination of customer solarand storage billing compensation mechanisms, additional utility incentives, other utility support, etc.

Various adoption scenarios capture multifaceted programs targeting various property types and communities No.ScenariosNarrative & Philosophy0Business as UsualReflects current GWP policies at business-as-usual conditions without any additional incentive programs or other utility support.1Continue Current NEMReflects current NEM policies without new incentive programs, but with improved outreach, support, and improved permitting processes.2Targeted MF LMI AdoptionAims to reach as much adoption as possible while maintaining high standards for equitable implementation. Focuses on minimal cost shifting and promotes MF LMI/DAC adoption via direct install programs.3BalancedAims to reach a balance between S2 and S4, with a focus on increasing customer adoption while reducing cost shifting potential, supplemented with MF LMI/DAC upfront incentives as needed.4Widespread AdoptionAims to reach adoption goal with an emphasis on customer-sited solar and storage. Focuses on maximizing adoption with supplemental upfront incentives as needed.5Direct InstallServes as a high-cost bookend under which GWP direct installs up to 10% of customer with solar. Emphasis on MF properties (lower cost per customer) and adoption in LMI/DACs.

Encouraging Customer Adoption
Realizing Value for Grid & CommunityManaging Cost-Shift & Affordability Balancing Multiple Objectives
Scenarios are guided by values from stakeholders, policy, and GWP , and for each scenario the proposed program portfolio was scored on how well it captured each value from multiple perspectives.

S0 and S5 represent bookend scenarios derived from standalone, simplified back-of-envelope calculations, intended to provide a broad estimate of magnitude. 284 of 559

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Other Utility Support
The scenarios outline different pathways towards Glendale’s DER adoption targetNEM CompensationAdditional Incentives*Renter and LMI Customer Barriers S1S2Targeted LMI MF Adoption
S3Balanced
S4Widespread Adoption
S5Direct Install
Net energy metering at retail ratesNet energy billing at avoided costs Net energy metering at retail rates
Net energy metering at retail rates
Net energy billing above avoided costs but below retail rates Federal and stateFederal and state, utility direct install for LMI/DAC MF customers Federal and state, and direct install for MF renter LMI/DAC customers Federal and state, 5-yr payback utility incentive for all MF customers Federal and state, 7-yr payback utility incentive for LMI/DAC MF buildings Persist
Optimistic outlook on enhanced community outreach and support, along with improved permitting processes starting early 2025 Optimistic outlook for providing renter and LMI customer solutions starting early 2025 S0Business as UsualNet energy metering at retail ratesFederal and statePersistAt the Current Level PersistAt the Current Level
Evaluate Adoption StrategiesReferenceHypothetical Feasibility *Additional incentives is a general representation of all types of incentives including potential upfront incentives and performance-based incentives offered by GWP. Assuming receipt of GWP incentives requires customers dispatch battery storage against utility signals to maximize community benefits.

Continue Current NEM
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Assumptions on Additional Incentives and Solutions for Renter and LMI CustomersAdditional incentives modeled are a general representation of all types of incentives including potential upfront incentives and performance-based incentives offered by GWP•Assuming receipt of GWP incentives requires customers to dispatch battery storage against utility signals to maximize community benefits Assume renter and LMI access can be provided with virtual solar or other financing solutions starting early 2025•In practice, real-world solutions to explore later may include on-bill financing options, green leases, and off-site solar solutions like community solar, solar share, green rate, and virtual net metering, all of which are pivotal for cost reduction and broadening access to multi-family, low-income, or tenant households 286 of 559

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ÊTo distinguish consumer decision-making among different household types, E3 assigned varying discount rates (investment hurdle rates) based on income levels and customer sectors, accounting for the frictions to DER adoption.•Higher discount rates (16%) were assigned to Multifamily, C&I, and LMI customers, while other customers received a 7% rate (normal discount rate assumption in this study), determined based on historical solar and storage adoption in the City of Glendale.•These rates were applied solely to distinguish consumer adoption behavior in the adoption model and were not used in the downstream cost-benefit analysis.ÊSpecifically, renters and multifamily households may encounter a “split incentive” issue, where tenants who benefit from bill savings do not control the rooftop, and building owners who make upgrades don’t directly benefit from utility savings. There is no existing work to mathematically characterize split incentives; therefore, to model the effect of split incentives on adoption, two scenarios were considered:•Split Incentives Fully Resolved: Renters are assumed to behave similarly to owners, leading to the application of the same discount rate for both groups.•Split Incentives Persist: Renters are assumed to have a significantly higher discount rate (100%), effectively preventing the adoption of solar and storage systems in rental units.ÊFor this study, E3 focused on quantifying the impact of resolving split incentives on DER adoption, rather than evaluating the effectiveness of specific solutions. In practice, solutions for addressing split incentives between owners and tenants typically involve programs designed to realign financial incentives for energy measures (details in the Potential Program and Policy Options section).

Clarifying Assumptions in Modeling the Resolution of Split IncentivesBuilding TypeOwnership StatusIncome ClassDiscount Rate(Split Incentives Fully Resolved)Discount Rate(Split Incentives Persist)Single-FamilyOwnerLMI16%16%Single-FamilyOwnerNon-LMI7%7%Single-FamilyTenantLMI16%100%Single-FamilyTenantNon-LMI7%7%3 Multi-Family Low-RiseOwnerLMI16%16%Multi-Family Low-RiseOwnerNon-LMI16%16%Multi-Family Low-RiseTenantLMI16%100%Multi-Family Low-RiseTenantNon-LMI16%100%Multi-Family High-RiseOwnerLMI16%16%Multi-Family High-RiseOwnerNon-LMI16%16%Multi-Family High-RiseTenantLMI16%100%Multi-Family High-RiseTenantNon-LMI16%100%C&I SmallOwnerN/A16%16%C&I SmallTenantN/A16%100%C&I MediumOwnerN/A16%16%C&I MediumTenantN/A16%100%C&I LargeOwnerN/A16%16%C&I LargeTenantN/A16%100%E3’s approach draws on methodologies established in NREL studies1, 2, which were further tailored to fit the specific needs of the analysis.1.“Chapter 8: Equitable Rooftop Solar Access and Benefits.” In LA100 Equity Strategies, National Renewable Energy Laboratory. NREL/TP-7A40-85955. https://www.nrel.gov/docs/fy24osti/85955.pdf. 2.2. Affordable and Accessible Solar for All: Barriers, Solutions, and On-Site Adoption Potential. Golden, CO: National Renewable Energy Laboratory. NREL/TP-6A20-80532. https://www.nrel.gov/docs/fy21osti/80532.pdf.3.The adjusted discount rate for split incentives applies to all renters except non-LMI single-family tenants, due to their historically high adoption rates. 287 of 559

Section 7.3 Key Model Results
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Key Results: Bill Savings and Utility Incentive Levels by ScenarioVariations in customer segments may lead to a range of outcomesNEM Compensation 2025 Level ($/kWh)Additional Incentives* 2025 Level ($/W) S1Continue Current NEM
S3Balanced
S4Widespread Adoption
S5Direct Install
Net energy metering at retail rates
Net energy metering at retail rates
Net energy metering at retail rates
Net energy billing above avoided costs but below retail rates Federal and state
Federal and state, utility direct install for all MF renter LMI/DAC customers Federal and state, 5-yr payback utility incentive for all MF customers Federal and state, 7-yr payback utility incentive for LMI/DAC MF buildings S0Business as UsualNet energy metering at retail ratesFederal and state Evaluate Adoption StrategiesReferenceHypothetical Feasibility *Additional incentives is a general representation of all types of incentives including potential upfront incentives and performance-based incentives offered by GWP. Assuming receipt of GWP incentives requires customers dispatch battery storage against utility signals to maximize community benefits.

0.13-0.28

0.00 0.11-0.22

0.06-0.25

0.13-0.28

0.00 0.13-0.28

0.00 N/A
N/A

0.00 0.00

1.3-1.5

1.4-1.5

1.0-1.2

1.7-1.8

0.00 0.00
S2Targeted LMI MF AdoptionNet energy billing at avoided costsFederal and state, utility direct install for LMI/DAC MF customers

0.09-0.19

0.08-0.28

2.6 1.65
N/A
N/A
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Key Results: Adoption Level, Equity, and Key Observations by ScenarioThese adoption scenarios represent the best-case adoption forecast *Additional incentives is a general representation of all types of incentives including potential upfront incentives and performance-based incentives offered by GWP. Assuming receipt of GWP incentives requires customers dispatch battery storage against utility signals to maximize community benefits.

Key ObservationsNEM Compensation 2027Equity & Access2027Customer AdoptionOther Utility SupportAdditional Incentives*Renter and LMI Customer Barriers (Split Incentives) S1Continue Current NEMS2Targeted LMI MF Adoption
S3Balanced
S4Widespread AdoptionS5Direct Install
Net energy metering at retail ratesNet energy billing at avoided costs Net energy metering at retail rates
Net energy metering at retail rates
Net energy billing above avoided costs but below retail rates Federal and state
Federal and state, utility direct install for LMI/DAC MF customers Federal and state, and direct install for all MF renter LMI/DAC customers Federal and state, 5-yr payback incentive for all multifamily customers Federal and state, 7-yr payback utility incentive for LMI/DAC MF buildings Persist

9.6 %60 MW

1.5 %5 MW

11.6 %58 MW

2.7 %7 MW

11.8 %59 MW

2.1 %6 MW

15.8 %70 MW

2.0 %6 MW
MF Renter LMI10%10%16%13%22%18%MF Renter LMI44%46%42%56%58%54%MF Renter LMI41%43%37%55%59%54%MF Renter LMI51%52%40%72%67%47%

5.2 %39 MW

0.8 %3 MW
MF Renter LMI5%12%11%0%11%11%
Optimistic outlook for providing renter and LMI customer solutions starting early 2025 Optimistic outlook on enhanced community outreach and support, along with improved permitting processes starting early 2025 Net energy metering at retail ratesFederal and stateS0Business as UsualPersistAt the Current Level Evaluate adoption strategiesReferenceHypothetical Feasibility PersistAt the Current Level

10.0 %48 MW

10.0 %10 MW
MF Renter LMI51%54%53%92%93%93%
To achieve the goal, utility interventions are necessary to accelerate and further promote adoption.

Enhancing utility support alone can boost solar adoption to reach 10% adoption by 2030 without further utility interventions, but has limited impact on promoting battery storage adoption.Utility incentives and virtual solar solutions are needed in reaching the adoption target along with improving utility support. Positive but still limited impact on storage adoption.Improving NEM equity with reasonable upfront incentives for MF LMI/DAC customers could also work, if implemented along with improving utility support. Positive but still limited impact on storage adoption.Maintaining current NEM with strong (lower but broader) upfront incentives for all MF customers could also work, if implemented along with improving utility support. Positive but still limited impact on storage adoption.Targeted direct install alone could work as an adoption goal compliance measure, but with significant utility investment (huge cost premium compared with lower-cost utility-scale alternatives) . 290 of 559

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Key Results: Additional Key Observations by ScenarioVariations in customer segments may lead to a range of outcomesSolar Storage S1Continue Current NEM
S3Balanced
S4Widespread Adoption
S5Direct Install
S0Business as Usual
At the current annual adoption rate, solar adoption is projected to reach 5.2% under business-as-usual conditions and achieve 7.4% by 2030. To achieve the goal, utility interventions are necessary to accelerate and further promote adoption.

Evaluate Adoption StrategiesReferenceHypothetical Feasibility *Additional incentives is a general representation of all types of incentives including potential upfront incentives and performance-based incentives offered by GWP. Assuming receipt of GWP incentives requires customers dispatch battery storage against utility signals to maximize community benefits.

S2Targeted LMI MF Adoption
Enhancing customer outreach and support and simplifying the permitting process can boost adoption. Without further utility interventions, adoption may fall short of the 2027 target, but it would be enough to reach 10% adoption by 2030.

Maintaining current NEM policies with strong (lower but broader) upfront incentives for all MF customers could also help reach the target, if implemented along with improving customer outreach, support, and the permitting process.

Improving NEM equity with reasonable upfront incentives for MF LMI/DAC customers could also help reach the target, if implemented along with improving customer outreach, support, and the permitting process.

Utility interventions to provide additional utility support and incentives and increase access for renter and LMI customers are needed to reach the adoption target. Unlocking adoption potential from the MF sector creates opportunities to maximize the equity of the current net metering mechanism, with co-benefits of increasing the cost-effectiveness of storage additions to customer solar systems.

At the current annual adoption rate, solar adoption is projected to reach 0.8% under business-as-usual conditions and achieve 2.0% by 2030. To achieve the goal, utility interventions are necessary to accelerate and further promote adoption.

Enhancing customer outreach and support and simplifying the permitting process alone has limited impact on promoting adoption, mainly due to the poor economic performance of adding battery storage systems to customer solar.

Additional utility incentives through direct install programs, coupled with the enhanced value proposition under NEB, promote greater adoption of customer storage (mostly SF households). Storage adoption remains insufficient to meet the adoption target by 2027, and even by 2030. This is primarily attributed to historically low adoption rates and the continued mediocre economic performance of BTM storage systems.Additional utility incentives through upfront incentives promote greater adoption of customer storage (mix of SF/MF households). While the attachment rate of storage to solar systems falls within the average range, it remains insufficient to meet the adoption target by 2027, and even by 2030. This is primarily attributed to historically low adoption rates and the continued mediocre economic performance of BTM storage systems.Additional utility incentives through upfront incentives promote greater adoption of customer storage (mostly MF households). While the attachment rate of storage to solar systems falls within the average range, it remains insufficient to meet the adoption target by 2027, and even by 2030. This is primarily attributed to historically low adoption rates and the continued mediocre economic performance of BTM storage systems.

N/AN/A
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2027 Customer Adoption by Scenario – SolarIncluding solar-only and solar + storage systems, cumulative adoption by 2027 S1: Continue Current NEMS2: Targeted MF LMI AdoptionS3: BalancedS4: Widespread Adoption LMI: Low and Moderate IncomeMF: Multi-family
10%
12% 12%
16%
2%
5%
4%
6%
1%
5%
5%
8%
1%
6% 5%
8%
0%
2%
4%
6%
8%
10%
12%
14%
16%
18%
S1 S2 S3 S4
Total and LMI Adoption in 2027 Relative to All GWP Customers (%) Total Adoption
LMI Adoption
MF Adoption
Renter Adoption
% of Total GWP Customers

9.6%

11.7% 11.8%

15.8%

1.6%

4.9% 4.4%

6.3%

1.0%

5.1% 4.8%

8.0%

0.9%

5.3% 5.1%

8.2%

0.0%

2.0%

4.0%

6.0%

8.0%

10.0%

12.0%

14.0%

161
2027 Customer Adoption by Scenario – Battery StorageIncluding solar + storage systems, cumulative adoption by 2027 LMI: Low and Moderate IncomeMF: Multi-family

1.5%

2.7% 2.1% 2.0%

0.3%

1.4% 1.1% 1.0%

0.2%

1.5% 1.2% 1.4%

0.3%

1.5% 1.2% 1.4%

0.0%

2.0%

4.0%

6.0%

8.0%

10.0%

12.0%

14.0%

16.0%
S1 S2 S3 S4
Adoption in 2027 Relative to All GWP Customers (%)
Total Adoption
LMI Adoption
MF Adoption
Renter Adoption
% of Total GWP Customers

1.5%

2.7%

2.1% 2.0%

0.3%

1.4% 1.1% 1.0%

0.2%

1.5% 1.2% 1.4%

0.3%

1.5% 1.2% 1.4%

0.0%

2.0%

4.0%

6.0%

8.0%

10.0%

12.0%

14.0%

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Most of the examined adoption-accelerating program portfolios increase solar access•The share of customer solar adoption attributed to multifamily, renter, or LMI customers increases in most adoption scenarios due to enhanced utility support, enhanced options for renter and LMI customers, improved net metering compensation, and targeted additional incentives Reference Scenario (S0) (2023 Level)Range of Scenario Results (S1-S4) Multifamily %
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
2024
2025
2026
2027
2028
2029
2030
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
2024
2025
2026
2027
2028
2029
2030
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
2024
2025
2026
2027
2028
2029
2030
Renter %LMI %
Share of MF Adoption in Total Adoption (%)
Share of Renter Adoption in Total Adoption (%)
Share of LMI Adoption in Total Adoption (%)
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All examined adoption-accelerating program portfolios increase battery storage access•The share of customer battery storage adoption attributed to multifamily, renter, or LMI customers increases in all adoption scenarios due to enhanced utility support, enhanced options for renter and LMI customers, improved net metering compensation, and targeted additional incentives•Although access improves, storage adoption does not meet the target due to high upfront costs and minor bill savings Range of Scenario Results (S1-S4)
Multifamily %Renter %LMI %
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
2024
2025
2026
2027
2028
2029
2030
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
2024
2025
2026
2027
2028
2029
2030
0%
10%
20%
30%
40%
50%
60%
70%
80%
90%
100%
2024
2025
2026
2027
2028
2029
2030
Reference Scenario (S0) (2023 Level)
Share of MF Adoption in Total Adoption (%)
Share of Renter Adoption in Total Adoption (%)
Share of LMI Adoption in Total Adoption (%)
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Adoption scenarios project theoretical upper bounds for adoption, resulting in net ratepayer costs and rate impacts 0%
5%
10%
15%
20%
25%
30%
2024
2025
2026
2027
2028
2029
2030
0%
5%
10%
15%
20%
25%
30%
2024
2025
2026
2027
2028
2029
2030
•The adoption scenarios project upper bounds for solar adoption by 2027. The adoption level results will be further limited by implementation barriers, customer adoption behavior, and other financial and non-economic barriers that customers face.•All proposed strategies impose more costs on GWP ratepayers and lead to further increases in retail rates.•There are alternatives to current NEM that can still promote local solar and storage but also reduce costs to GWP ratepayers.

165
All examined program portfolios require significant utility investments, increasing rates and bills for all GWP customers•Across all adoption scenarios, retail rates are anticipated to increase between 6% and 11% by 2030 due to solar and storage programs on top of other anticipated sources of rate growth•This means that the average LMI customer will pay between $4 and $6 more per month on electricity, or $48 to $72 per year Range of Scenario Results (S1-S4)
Rate Impacts (¢/kWh)Rate Impact (%)Avg. LMI Bill Impact ($/month)

0.0 1.0

2.0 3.0

4.0 5.0

6.0 7.0

8.0 2025
2030

0.0 0.5

1.0 1.5

2.0 2.5

3.0 2025
2030
Compared with rates w/o post-2023 solar and storageCompared with rates w/o post-2023 solar and storageCompared with monthly bills w/o post-2023 solar and storage Reference Scenario (S0) (2023 Level)YearYearYear
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Section 7.4Modeling Approach, Inputs, and Assumptions
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ÊE3 developed prototypical customer shapes using NREL ResStock and ComStock and leveraged work with the CPUC and LBNL on modeling flexible loadsÊE3 performed DER optimal dispatch simulation through its RESTORE model and identified appropriate rate signals to guide dispatch providing grid value E3 quantified the dispatchable capacity and demand reduction potential of DERs for valuation and rate design considerations A broad range of technologies
Market prices, utility ratesOptimal dispatchMarket revenues or customer savings

RESTORE
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E3 utilized its in-house DER toolkit (RESTORE) to estimate DER adoption forecasts DER Portfolio
Energy Efficiency Measures & Voltage Optimization
Customer-Sited PV
Smart Water Heater
Smart HVAC
Managed EV Charging
Storage
Fossil Generator(e.g., fuel cell)
Load Shedding DR
20°
A broad range of DER
Resource planning data, utility ratesOptimal dispatchAdoption forecast

RESTORE
Output designed for utility and regulatory commission consideration including Standard Practice ManualA public version of RESTORE without the IDSM feature can be found here:CEC Docket Log 19-MISC-04, https://efiling.energy.ca.gov/Lists/DocketLog.aspx?docketnumber=19-MISC-04 The Integrated Demand Side Management (IDSM) feature of E3’s RESTORE model can be used to predict adoption of a range of DER technologies. For this study, E3 used it to predict solar and storage adoption for GWP customers.

LegendDispatchable for energy servicesDispatchable while providing non-energy servicesNon-dispatchable 300 of 559

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RESTORE estimates DER adoption based on dispatch and cost-effectivenessÊAdoption•Impacts of rate scenarios and sensitivities on cumulative adoption ÊCosts & Benefits•Detailed costs and benefits shedding light on how economics affect consumer adoption ÊDER Dispatch / Customer Load Impact•How DER affects BTM customer net load under different scenarios Adoption
Costs & Benefits
Customer Load ImpactHour 123456789101112131415161718192021222324JanFebMarAprMayJunJulAugSepOctNovDec 301 of 559

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GWP-Customized Workflow of the IDSM Feature of RESTORE
Incentive Program(s)Customer Benefits EvaluationCustomer Costs EvaluationAdoption Behavior SimulationSystem Benefits EvaluationBenefit Cost Analysis RESTORE Integrated Demand-Side Management (IDSM) Tool Flowchart ÊState and federal upfront incentivesÊScenario-specific utility incentives ÊNet present value (NPV) calculation of customer bill savingsÊVarying rate designs lead to different bill savings potential ÊNPV of project lifetime costs (upfront and recurring)ÊTechnology costs and trajectories based on NREL ATB data ÊCustomer economics (benefit / cost ratio) predict adoption from 2025 to 2030 ÊSolar and storage system dispatch used to evaluate GWP system-wide avoided costs and emissions reductions IDSM model outputs feed into the system-wide Benefit Cost Analysis 302 of 559

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RESTORE deploys bass diffusion adoption modeling considering DER cost-effectiveness ÊIDSM utilizes classic bass diffusion modelÊAn empirical market share model to determine the long-run market equilibrium of customer adoption•The relationship between economic attractiveness and maximum market share based on payback period or benefit-cost ratioÊA bass diffusion model explains the time dynamics and adoption path to thisequilibrium •The pace of adoption is controlled by year-to-year changes in economics•Adoption will be accelerated if economics substantially improve Incentive Program(s)Customer Benefits EvaluationCustomer Costs EvaluationAdoption Behavior SimulationSystem Benefits EvaluationBenefit Cost Analysis 303 of 559

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More than a dozen customer segments were captured in E3’s analysisÊIdentified 18 customer segments to represent diversity by customer sector, ownership, and income•Enabled segmentation of MF , renter, and LMI/DAC customers for equity analysisÊSegmented into three customer sectors•SF , MF , and C&IÊClassified into six building types•SF: Single-Family•MF: Multi-Family Low-Rise vs. High-Rise•C&I: Small, Medium, LargeÊDistinguished by two ownership statuses•Owner vs. TenantÊCategorized by two income classes•LMI and non-LMI (general market) Customer Segmentation in RESTORE ModelingCustomer No.Customer SectorBuilding TypeOwnership StatusIncome Class1SFSingle-FamilyOwnerLMI2SFSingle-FamilyOwnerNon-LMI3SFSingle-FamilyTenantLMI4SFSingle-FamilyTenantNon-LMI5MFMulti-Family Low-RiseOwnerLMI6MFMulti-Family Low-RiseOwnerNon-LMI7MFMulti-Family Low-RiseTenantLMI8MFMulti-Family Low-RiseTenantNon-LMI9MFMulti-Family High-RiseOwnerLMI10MFMulti-Family High-RiseOwnerNon-LMI11MFMulti-Family High-RiseTenantLMI12MFMulti-Family High-RiseTenantNon-LMI13C&ISmallOwnerN/A14C&ISmallTenantN/A15C&IMediumOwnerN/A16C&IMediumTenantN/A17C&ILargeOwnerN/A18C&ILargeTenantN/A 304 of 559

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Premises of a Successful Adoption PlanÊStrong Outreach, Education, Support: assumed the level of outreach is not a constraint, and comprehensive outreach and educational campaigns are present which enhance awareness and empower residents to make informed decisions with understanding of the underlying economics.ÊImproved Permitting Process: assumed permitting process is not a constraint, and a faster, easier, and scalable permitting, interconnection, and approval process to facilitate smoother installations is present.ÊIntelligible Program Design: assumed information access and intelligibility of program design is not a constraint for adoption.ÊAddressing Split Incentives: modeled the split incentive assuming renters have a significantly higher discount rate than owners in cases where split incentives persist. A deep dive into what programs could mitigate split incentives is presented later.

Other Model AssumptionsÊModeling LMI Customers: LMI customers were assumed to have higher hurdle rates for DER economics, necessitating higher investment decision thresholds.ÊAdoption Sequencing: customers were assumed to consider adopting solar first, followed by potential adoption of storage. Only customers with existing solar installations would consider adding storage.ÊInterconnection Charges: charges related to interconnection are already accounted for in solar installation costs.ÊBuilding Stock: solar and storage mandate estimates were estimated via downstream analysis. Customer counts were assumed to remain static, with no changes in the building stock. New construction was considered separately (see next slide).ÊBuilding Electrification: the model assumed stable customer load profiles. Sensitivity of building electrification can be done as sensitivities in later stages.

Key model assumptions are important to note for accurate interpretation of adoption forecastsSeveral prerequisites are fundamental for a successful adoption plan. For the purposes of this study, E3 made the following assumptions to assume the existence of these premises. For instance, the model assumes that customers have complete information about the program, its costs and benefits, and will make economic decisions accordingly, along with other key assumptions. 305 of 559

Section 7.5Detailed Model Results: Solar & Battery Storage 306 of 559

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0 50
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Glendale New Privately Owned Housing Unit Authorizations Single-family Units (Historical)Single-family Units (Forecast - Exponential Smoothing) U.S. Census Bureau Building Permits Survey, # of Units, Single-family Forecast
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Glendale New Privately Owned Housing Unit Authorizations Multifamily Units (Historical)Multifamily Units (Forecast - Exponential Smoothing) U.S. Census Bureau Building Permits Survey, # of Units, Multi-family Forecast
Building code-compliant solar and storage adoption from new construction contributes to achieving the adoption targetÊGlendale has a local “reach code” that adopts the local amendments to the 2022 California Energy Code (Title 24, Part 6, and Part 11) that provide local, cost-effective standards for new residential, non-residential, and hotel and motel buildings that exceed the minimum standards of the 2022 California Energy Code and 2022 California Green Building Standards Code. Requirements vary based on locations and building types, with waivers and exceptions available as needed.

ÊFor the purposes of this study, future growth in residential new construction was estimated utilizing building permit survey data from 1990 to 2022.•Single-family: 80 units/yr (0.33% annual growth)•Multi-family: 290 units/yr (0.54% annual growth)•Commercial & Industrial: 63 units/yr (0.48% annual growth)** Single-family: 80 units/yr*
Multi-family: 290 units/yr*
•The 2023 values were estimated by applying exponential smoothing to historical data from 1990 to 2022, employing a short-term time series forecasting method. Future annual growth was assumed to mirror the 2023 forecast as a conservative estimate.** Commercial and Industrial new construction was estimated by mirroring the overall new construction growth rate from the residential sector, multiplied by 13,184 units reported in the GWP 2023 Annual Report.

0.33% annual growth of 24,000 customers

0.54% annual growth of 54,000 customers
Solar•SF: All newly constructed single-family buildings must have new solar PV systems/modules (Title 24).•MF, C&I: Install a PV system that offsets 100% of building electricity, or at least covers 50% of gross roof space area (Reach Code).For the purposes of this study, E3 assumed SF, MF, and C&I new construction comes with PV systems at average PV capacity accounting for roof and size limits.

Battery Storage•SF: No requirement.•MF High-rise, C&I: All buildings required to have solar PV must also have battery storage (Title 24).

For the purposes of this study, E3 assumed MF and C&I's new construction includes a 2-hour battery storage size to cover customer annual peak demand. 307 of 559

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Cumulative Mandated Adoption from New Construction
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Customer-sitedSolar, # of New Construction Units
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Cumulative Mandated Adoption from New Construction
Commercial & Industrial
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Customer-sitedStorage, # of New Construction Units
ÊBy the end of 2027, building code-compliant customer solar adoption could have the potential to reach 1,700+ units since the start of 2024.•Approximately 20% of the 10% customer penetration target•For the purposes of this study, E3 assumed SF , MF , and C&I new construction comes with PV systems at average PV capacity accounting for roof and size limits Building code-compliant solar and storage adoption from new construction will be importantÊBy the end of 2027, building code-compliant customer storage adoption could have the potential to reach 1,400+ units since the start of 2024.•Approximately 15% of the 10% customer penetration target•For the purposes of this study, E3 assumed MF and C&I's new construction includes a 2-hour battery storage size to cover customers' annual peak demand *Requirements for solar installations may vary based on location and building type. Waivers and exceptions are available as needed. In this study, a 90% derating factor was applied to represent exceptions and waivers. This factor accounts for uncertainties in specific building designs. It is crucial to note that this assumption requires further study to validate its accuracy. 1559 1277
Account for 90% waiver and exception derate*Account for 90% waiver and exception derate* 308 of 559

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2,924 5,023 7,241
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25,000
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GWP Customer Solar Penetration -Business-as-Usual (BAU) Scenario New Constr ucti on
Existing Buildings - C&I
Existing Buildings - MF
Existing Buildings - SF
City Council Target
# of GWP Electric Service Customers
12%12%12%
2023 2027 2030
Owner vs Renter
OwnerRenter
11%11%11%
2023 2027 2030
LMI vs Non-LMI
Non-LMILMI
5% 5% 5%
2023 2027 2030
SF vs MF vs C&I
SFMFCom

28.2 39.0 50.4
2023 2027 2030
Nameplate Capacity (MW)
*Excluding newconstruction *Excluding newconstruction *Excluding newconstruction Customer Solar and Storage Adoption Modeling ResultsScenario 0 – Business-as-Usual (Solar) This scenario reflects current GWP policies without new incentive programs and without improved outreach, support, and improved permitting process. The adoption forecast was developed using historical adoption data by customer segment, calibrated through a Bass Diffusion curve.ÊThis scenario is based on:•Stacking of available federal, state funding and applicable tax credits•NEM at retail rate without virtual net metering or off-site solar programs•No additional utility incentives and follow current feed-in-tariff program rules•No additional enhanced community outreach and support, along with improved permitting processes starting early 2025•Split incentive issue for tenants persists throughout the analysis periodÊExpected adoption level:•2027 customer penetration: 5.2%•2030 customer penetration: 7.4% •Nameplate capacity: 39 MW by 2027, and 50 MW by 2030ÊKey takeaways:•At the current rate of annual adoption, solar adoption is projected to reach 5.2% under business-as-usual conditions and achieve 7.4% by 2030. To achieve the goal, utility interventions are necessary to accelerate and further promote adoption.•Adoption is dominated by owner-occupied, single-family, non-LMI households 309 of 559

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Customer Solar and Storage Adoption Modeling ResultsScenario 0 – Business-as-Usual (Battery Storage)This scenario reflects current GWP policies without new incentive programs and without improved outreach, support, and improved permitting processes. The adoption forecast was developed using historical adoption data by customer segment, calibrated through a Bass Diffusion curve.ÊThis scenario is based on:•Stacking of available federal and state funding and applicable tax credits•NEM at retail rate without virtual net metering or off-site solar programs•No additional utility incentives and follow current feed-in-tariff program rules•No additional enhanced community outreach and support, along with improved permitting processes starting in early 2025•Split incentive issue for tenants persists throughout the analysis periodÊExpected adoption level:•2027 customer penetration: 0.8% (14% attachment rate)•2030 customer penetration: 2.0% (27% attachment rate)•Nameplate capacity: 3 MW by 2027, and 6 MW by 2030ÊKey takeaways:•At the current rate of annual adoption, solar adoption is projected to reach 0.8% under business-as-usual conditions and achieve 2.0% by 2030. To achieve the goal, utility interventions are necessary to accelerate and further promote adoption.•Adoption is dominated by owner-occupied, single-family, non-LMI households•Notable adoption mandate observed in new construction 185 725 1,968
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30,000
35,000
20232024202520262027202820292030
GWP Customer Storage Penetration -Business-as-Usual (BAU) Scenario New Constr ucti onExisting Buildings - C&I
Existing Buildings - MFExisting Buildings - SFCity Council Target # of GWP Electric Service Customers
11%11%11%
2023 2027 2030
Owner vs Renter
OwnerRenter
11%11%11%
2023 2027 2030
LMI vs Non-LMI
Non-LMILMI
0% 0% 0%
2023 2027 2030
SF vs MF vs C&I
SFMFCom

1.3 2.8 6.2
2023 2027 2030
Nameplate Capacity (MW)
*Excluding newconstruction *Excluding newconstruction *Excluding newconstruction 310 of 559

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Customer Solar and Storage Adoption Modeling ResultsScenario 1 – Continue Current NEM (Solar) This scenario reflects current GWP policies without new incentive programs but with improved outreach, support, and permitting processes.ÊThis scenario is based on:•Stacking of available federal and state funding and applicable tax credits•NEM at retail rate without virtual net metering or off-site solar programs•No additional utility incentives and follow current feed-in-tariff program rules•Optimism regarding enhanced community outreach and support, along with improved permitting processes starting in early 2025•Split incentive issue for tenants persists throughout the analysis periodÊExpected adoption level:•2027 customer penetration: 9.6%•2030 customer penetration: 15.2% •Nameplate capacity: 60 MW by 2027, and 90 MW by 2030ÊKey takeaways:•Enhancing customer outreach and support and simplifying the permitting process can boost adoption. Without further utility interventions, adoption may fall short of the 2027 target, but it would be enough to reach 10% adoption by 2030.•Under current NEM, there is stable growth in SF adoption, particularly among owner-occupied, non-LMI households•Limited MF growth under current NEM due to split incentives, stemming from ownership dynamics•The C&I sector has fewer customers but larger average installations, making it a key contributor to reaching the 100 MW DER capacity target.•Notable adoption mandate observed in new construction S1 adoption analysis does not differentiate existing buildings and new construction 311 of 559

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Customer Solar and Storage Adoption Modeling ResultsScenario 1 – Continue Current NEM (Battery Storage)This scenario reflects current GWP policies without new incentive programs but with improved outreach, support, and permitting processes.ÊThis scenario is based on:•Stacking of available federal and state funding and applicable tax credits•NEM at retail rate without virtual net metering or off-site solar programs•No additional utility incentives and follow current feed-in-tariff program rules•Optimism regarding enhanced community outreach and support, along with improved permitting processes starting in early 2025•Split incentive issue for tenants persists throughout the analysis periodÊExpected adoption level:•2027 customer penetration: 1.5% (16% attachment rate)•2030 customer penetration: 2.5% (16% attachment rate)•Nameplate capacity: 5 MW by 2027, and 8 MW by 2030ÊKey takeaways:•Enhancing customer outreach and support and simplifying the permitting process alone has limited impact on promoting adoption, mainly due to the poor economic performance of adding battery storage systems to customer solar.–Substantial upfront costs–Comparatively diminished benefits including lack of energy arbitrage benefits (low TOU participation, symmetric NEM rate schedule, etc.) and less quantifiable resiliency benefits•Adoption is dominated by owner-occupied, single-family, non-LMI households•Most of the new adoption will come from building code-compliant system installation from new construction 185 1,490 2,445
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35,000
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GWP Customer Storage Penetration -No New Program Scenario New Constr ucti onExisting Buildings - C&IExisting Buildings - MFExisting Buildings - SFCity Council Target # of GWP Electric Service Customers
11%22%22%
2023 2027 2030
Owner vs Renter
OwnerRenter
11%18%18%
2023 2027 2030
LMI vs Non-LMI
Non-LMILMI
0% 13%13%
2023 2027 2030
SF vs MF vs C&I
SFMFCom

1.3 5.1 8.0
2023 2027 2030
Nameplate Capacity (MW)
*Excluding newconstruction *Excluding newconstruction *Excluding newconstruction 312 of 559

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Customer Solar and Storage Adoption Modeling ResultsScenario 2 – Targeted LMI MF Adoption (Solar) This scenario aims to reach as much adoption as possible while maintaining high standards for equitable implementation. Focus on minimal cost shifting and promoting LMI/DAC adoption via direct install programs.ÊThis scenario is based on:•Stacking of available federal and state funding and applicable tax credits•NEB and VNEB programs are priced at avoided costs starting early 2025•Implementation of direct install program targeting MF LMI/DAC starting in early 2025•Optimistic outlook on enhanced community outreach and support, as well as improved permitting processes starting in early 2025•Assume split incentives are completely resolved starting in early 2025ÊExpected adoption level:•2027 customer penetration: 11.6%•2030 customer penetration: 20.8% •Nameplate capacity: 58 MW by 2027, and 88 MW by 2030ÊKey takeaways:•Utility interventions to provide additional incentives and resolve split incentives are needed to reach the adoption target, along with improving customer outreach, support, and the permitting process. Unlocking adoption potential from the MF sector creates opportunities to maximize the equity of the current net metering mechanism, with co-benefits of increasing the cost-effectiveness of storage additions to customer solar systems (discussed in the next slide).•Lower SF growth under NEB due to lower export compensation rate, which improves equity by reducing cost shifts to non-adopters•With solutions to split incentives and direct install programs targeted at MF LM/DAC households, the multifamily sector has dramatic adoption growth since 2025, and solar access expands outside single-family and becomes balanced 313 of 559

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Customer Solar and Storage Adoption Modeling ResultsScenario 2 – Targeted LMI MF Adoption (Battery Storage)This scenario aims to reach as much adoption as possible while maintaining high standards for equitable implementation. Focus on minimal cost shifting and promoting LMI/DAC adoption via direct install programs.ÊThis scenario is based on:•Stacking of available federal and state funding and applicable tax credits•NEB and VNEB programs are priced at avoided costs starting in early 2025•Implementation of a direct install program targeting MF LMI/DAC starting in early 2025•Optimistic outlook on enhanced community outreach and support, as well as improved permitting processes starting in early 2025•Assume split incentives are completely resolved starting in early 2025ÊExpected adoption level:•2027 customer penetration: 2.7% (23% attachment rate)•2030 customer penetration: 4.4% (21% attachment rate)•Nameplate capacity: 7 MW by 2027, and 11 MW by 2030ÊKey takeaways:•Additional utility incentives through direct install programs, coupled with the enhanced value proposition under NEB, promote greater adoption of customer storage (mostly SF households). While the storage attachment rate to solar systems falls within the state average range (6%-19% by income level), it remains insufficient to meet the adoption target by 2027 and even by 2030. This is primarily attributed to historically low adoption rates and the continued mediocre economic performance of BTM storage systems.•With the export rate being lower than the import rate under NEB/VNEB, storage systems are better off and have a higher value in maximizing household self-consumption, thus observing adoption growth from the residential and commercial sectors•MF growth increased as expected because of the targeted LMI MF direct install program that covers the initial upfront cost 185 2,562 4,277
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GWP Customer Storage Penetration -Targeted MF LMI Adoption Scenario New Constr ucti onExisting Buildings - C&I
Existing Buildings - MFExisting Buildings - SFCity Council Target # of GWP Electric Service Customers
11%
58%58%
2023 2027 2030
Owner vs Renter
OwnerRenter
11%
54%54%
2023 2027 2030
LMI vs Non-LMI
Non-LMILMI
0%
56%56%
2023 2027 2030
SF vs MF vs C&I
SFMFCom

1.3 6.8 10.9
2023 2027 2030
Nameplate Capacity (MW)
*Excluding newconstruction *Excluding newconstruction *Excluding newconstruction 314 of 559

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Customer Solar and Storage Adoption Modeling Results Scenario 3 – Balanced (Solar) This scenario aims to reach a balance between S2 and S4, with a focus on increasing customer adoption while reducing cost shift, supplemented with MF LMI/DAC upfront incentives as needed.ÊThis scenario is based on:•Stacking of available federal and state funding and applicable tax credits•NEB/VNEB programs priced at avoided costs with adders to achieve 7-year payback periods for solar to promote adoption starting in early 2025•Introduction of additional 7-yr payback incentives for solar and storage specifically aimed at MF LMI/DAC households starting early 2025•Optimistic anticipation of enhanced community outreach and support, coupled with improved permitting processes starting in early 2025•Assume split incentives are completely resolved starting in early 2025ÊExpected adoption level:•2027 customer penetration: 11.8%•2030 customer penetration: 22.0% •Nameplate capacity: 59 MW by 2027, and 92 MW by 2030ÊKey takeaways:•Improving NEM equity with reasonable upfront incentives for MF LMI/DAC customers could also help reach the target, if implemented along with improving customer outreach, support, and the permitting process.•Slightly lower SF growth under NEB (with adder) due to a slightly lower export compensation rate, which improves equity by reducing cost shifts to non-adopters. Encourages more adoption than S2 (Targeted MF LMI Adoption) because an adder to promote adoption is included.•With solutions to split incentives and upfront incentive programs targeted at MF LMI/DAC households, the MF sector has dramatic adoption growth since 2025. This upfront incentive program is less deep than the direct install program in S1 and less broad than S3 for all MF households, so there is lower adoption but enough to achieve the goal and expand solar access outside of the SF sector. 315 of 559

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Customer Solar and Storage Adoption Modeling Results Scenario 3 – Balanced (Battery Storage)This scenario aims to reach a balance between S2 and S4, with a focus on increasing customer adoption while reducing cost shifts, supplemented with MF LMI/DAC upfront incentives as needed.ÊThis scenario is based on:•Stacking of available federal and state funding and applicable tax credits•NEB/VNEB programs priced at avoided costs with adders to achieve 7-year payback periods for solar to promote adoption starting in early 2025•Introduction of additional 7-yr payback incentives for solar and storage specifically aimed at MF LMI/DAC households starting early 2025•Optimistic anticipation of enhanced community outreach and support, coupled with improved permitting processes starting in early 2025•Assume split incentives are completely resolved starting in early 2025ÊExpected adoption level:•2027 customer penetration: 2.1% (18% attachment rate)•2030 customer penetration: 3.4% (16% attachment rate)•Nameplate capacity: 6 MW by 2027, and 9 MW by 2030ÊKey takeaways:•Additional utility incentives through upfront incentives promote greater adoption of customer storage (mix of SF/MF households). While the storage attachment rate to solar systems falls within the average range, it remains insufficient to meet the adoption target by 2027 and even by 2030. This is primarily attributed to historically low adoption rates and the continued mediocre economic performance of BTM storage systems.•With the export rate slightly lower than the import rate under NEB/VNEB, storage systems are slightly better off and have higher value in maximizing household self-consumption, thus observing adoption growth from the residential and commercial sectors•With additional upfront incentives for MF LMI/DAC households, more MF battery systems are expected to come online. This helps improve the equity distribution of storage access, though total adoption is still minimal due to customer storage's mediocre performance. 185 2,019 3,334
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GWP Customer Storage Penetration -Balanced Scenario
New Constr ucti onExisting Buildings - C&I
Existing Buildings - MFExisting Buildings - SFCity Council Target # of GWP Electric Service Customers
11%
59%66%
2023 2027 2030
Owner vs Renter
OwnerRenter
11%
54%62%
2023 2027 2030
LMI vs Non-LMI
Non-LMILMI
0%
55%64%
2023 2027 2030
SF vs MF vs C&I
SFMFCom

1.3 5.9 9.2
2023 2027 2030
Nameplate Capacity (MW)
*Excluding newconstruction *Excluding newconstruction *Excluding newconstruction 316 of 559

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Customer Solar and Storage Adoption Modeling Results Scenario 4 – Widespread Adoption (Solar) This scenario aims to reach the adoption goal with an emphasis on customer-sited solar and storage. Focus on maximizing adoption with supplemental upfront incentives as needed.ÊThis scenario is based on:•Stacking of available federal and state funding and applicable tax credits•NEM and VNEM are both set at retail rates starting in early 2025•Introduction of additional 5-yr payback incentives specifically aimed at MF households starting early 2025•Optimistic anticipation of enhanced community outreach and support, coupled with improved permitting processes starting in early 2025•Assume split incentives are completely resolved starting in early 2025ÊExpected adoption level:•2027 customer penetration: 15.8%•2030 customer penetration: 30.4% •Nameplate capacity: 70 MW by 2027, and 119 MW by 2030ÊKey takeaways:•Maintaining current NEM policies with strong (lower but broader) upfront incentives for all MF customers could also help reach the target, if implemented along with improving customer outreach, support, and the permitting process.•SF growth is forecasted to be the same as S1 since it is also under the current NEM at retail rates•With solutions to split incentives and upfront incentives targeted at all MF households, the multi-family sector has dramatic adoption growth since 2025, and solar access expands outside of the single-family sector and becomes balanced. 317 of 559

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Customer Solar and Storage Adoption Modeling ResultsScenario 4 – Widespread Adoption (Battery Storage)This scenario aims to reach the adoption goal with an emphasis on customer-sited solar and storage. Focus on maximizing adoption with additional upfront incentives as needed.ÊThis scenario is based on:•Stacking of available federal and state funding and applicable tax credits• NEM and VNEM are both set at retail rates starting in early 2025•Introduction of additional 5-yr payback incentives specifically aimed at MF households starting early 2025•Optimistic anticipation of enhanced community outreach and support, coupled with improved permitting processes starting in early 2025•Assume split incentives are completely resolved starting in early 2025ÊExpected adoption level:•2027 customer penetration: 2.0% (13% attachment rate)•2030 customer penetration: 3.4% (11% attachment rate)•Nameplate capacity: 6 MW by 2027, and 9 MW by 2030ÊKey takeaways:•Additional utility incentives through upfront incentives promote greater adoption of customer storage (mostly MF households). While the storage attachment rate to solar systems falls within the average range, it remains insufficient to meet the adoption target by 2027 and even by 2030. This is primarily attributed to historically low adoption rates and the continued mediocre economic performance of BTM storage systems.•SF growth is forecasted to be the same as S1 since it is also under the current NEM at retail rates where storage systems do not provide the value-add of maximizing self-consumption.•With the additional upfront incentives targeted at the MF sector, more MF battery systems are expected to come online. This helps improve the equity distribution of storage access, though total adoption is still minimal due to mediocre customer storage performance. 185 1,941 3,343
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GWP Customer Storage Penetration -Widespread Adoption Scenario New Constr ucti onExisting Buildings - C&IExisting Buildings - MFExisting Buildings - SFCity Council Target # of GWP Electric Service Customers
11%
67%76%
2023 2027 2030
Owner vs Renter
OwnerRenter
11%47%53%
2023 2027 2030
LMI vs Non-LMI
Non-LMILMI
0%
72%83%
2023 2027 2030
SF vs MF vs C&I
SFMFCom

1.3 5.5 8.7
2023 2027 2030
Nameplate Capacity (MW)
*Excluding newconstruction *Excluding newconstruction *Excluding newconstruction 318 of 559

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ÊAs a hypothetical scenario, scenario 5 explores the feasibility and cost implications of a hypothetical GWP Direct Install Program covering upfront costs of solar and storage (net of available federal IRA tax credits) to achieve 10% adoption of each by 2027 focusing on multi-family, renter, and low- to moderate-income customers. ÊEstimates build on the Business as Usual (Scenario 0) forecast and calculate the incremental system installations needed to reach the City Council Targets. ÊLaunching a direct install program would incur an estimated cost of $48 million for a program period of 2025-2027, covering upfront expenses alone (net of federal and state subsidies). This cost estimate does not cover NEM compensation for these systems which will be costly in the long run.

Customer Solar and Storage Adoption Modeling Results Scenario 5 – Direct Install Adoption (Solar and Battery Storage) Utility Upfront Costs of S5 Direct Install These systems were allocated to the “Multi-family, Renter, Low- and Moderate-Income” customer types within the model.This was intended to increase access to customers historically excluded from solar and storage adoption. It is also more cost-effective from the utility program perspective, as it involves smaller system sizes per customer and allows multiple customers to benefit from installing a single system. $25,121,798
$11,881,774 $11,421,279
$-
$3, 000,000
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2023 2024 2025 2026 2027
Ad ditional Storage
Solar Only
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2023 2024 2025 2026 2027
Ba seline Adoption For ecast Di rect Installations
2,924 3,364 3,859 4,411 5,023
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2,465
3,552
4,602
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Ba seline Adoption For ecast Di rect Installations
Customer Solar and Storage Adoption Modeling Results Scenario 5 – Direct Install Adoption (Solar and Battery Storage) Solar AdoptionStorage Adoption
# of Customers
# of Customers
Implementing direct installation of new solar systems for customers who have not previously installed solarImplementing direct installation of storage for existing solar systems and bundling it with new solar installations 320 of 559

189
2,924
9,625 11,843
-
5,000
10,000
15,000
20,000
25,000
30,000
35,000
20232024202520262027202820292030
GWP Customer Solar Penetration -Direct Install Scenario New Constr ucti on
Existing Buildings - C&IExisting Buildings - MF
Existing Buildings - SFCity Council Target
# of GWP Electric Service Customers
12%
54%46%
2023 2027 2030
Owner vs Renter
OwnerRenter
11%
53%45%
2023 2027 2030
LMI vs Non-LMI
Non-LMILMI
5%
51%42%
2023 2027 2030
SF vs MF vs C&I
SFMFCom

28.2 47.5 58.9
2023 2027 2030
Nameplate Capacity (MW)
*Excluding newconstruction *Excluding newconstruction *Excluding newconstruction Customer Solar and Storage Adoption Modeling Results Scenario 5 – Direct Install Adoption (Solar and Battery Storage) 185
9,625 10,867
-
5,000
10,000
15,000
20,000
25,000
30,000
35,000
20232024202520262027202820292030
GWP Customer Storage Penetration -Direct Install Scenario New Constr ucti onExisting Buildings - C&IExisting Buildings - MFExisting Buildings - SFCity Council Target # of GWP Electric Service Customers
11%
93%84%
2023 2027 2030
Owner vs Renter
OwnerRenter
11%
93%84%
2023 2027 2030
LMI vs Non-LMI
Non-LMILMI
0%
92%82%
2023 2027 2030
SF vs MF vs C&I
SFMFCom

1.3 9.9 13.3
2023 2027 2030
Nameplate Capacity (MW)
*Excluding newconstruction *Excluding newconstruction *Excluding newconstruction 321 of 559

Section 7.6 Detailed Model Results: Utility Incentives & Bill Savings 322 of 559

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Customer Solar Bill SavingsBuilding Type Ownership
Status
Income
Class S1 S2 S3 S4
Single-Family Tenant LMI $0.26 $0.13 $0.18 $0.26
Single-Family Tenant Non-LMI $0.27 $0.16 $0.20 $0.27
Single-Family Owner LMI $0.27 $0.13 $0.17 $0.27
Single-Family Owner Non-LMI $0.28 $0.16 $0.20 $0.28
Multi-Family Low-Rise Tenant LMI $0.23 $0.12 $0.16 $0.23 Multi-Family Low-Rise Tenant Non-LMI $0.24 $0.15 $0.18 $0.24 Multi-Family Low-Rise Owner LMI $0.24 $0.09 $0.15 $0.24 Multi-Family Low-Rise Owner Non-LMI $0.24 $0.15 $0.19 $0.24 Multi-Family High-RiseTenant LMI $0.23 $0.13 $0.17 $0.23 Multi-Family High-RiseTenant Non-LMI $0.24 $0.16 $0.19 $0.24 Multi-Family High-RiseOwner LMI $0.23 $0.11 $0.16 $0.23 Multi-Family High-RiseOwner Non-LMI $0.26 $0.19 $0.22 $0.26 C&I Small Tenant N/A $0.25 $0.14 $0.14 $0.25
C&I Small Owner N/A $0.25 $0.14 $0.14 $0.25
C&I Medium Tenant N/A $0.15 $0.11 $0.11 $0.15
C&I Medium Owner N/A $0.15 $0.11 $0.11 $0.15
C&I Large Tenant N/A $0.13 $0.11 $0.11 $0.13
C&I Large Owner N/A $0.13 $0.12 $0.12 $0.13
Building Type Ownership
Status
Income
Class S1 S2 S3 S4
Single-Family Tenant LMI $0.32 $0.18 $0.23 $0.32
Single-Family Tenant Non-LMI $0.33 $0.21 $0.25 $0.33
Single-Family Owner LMI $0.33 $0.17 $0.22 $0.33
Single-Family Owner Non-LMI $0.34 $0.21 $0.25 $0.34
Multi-Family Low-Rise Tenant LMI $0.28 $0.16 $0.21 $0.28 Multi-Family Low-Rise Tenant Non-LMI $0.29 $0.19 $0.23 $0.29 Multi-Family Low-Rise Owner LMI $0.29 $0.14 $0.19 $0.29 Multi-Family Low-Rise Owner Non-LMI $0.30 $0.20 $0.23 $0.30 Multi-Family High-RiseTenant LMI $0.28 $0.17 $0.21 $0.28 Multi-Family High-RiseTenant Non-LMI $0.29 $0.20 $0.24 $0.29 Multi-Family High-RiseOwner LMI $0.28 $0.15 $0.20 $0.28 Multi-Family High-RiseOwner Non-LMI $0.32 $0.24 $0.27 $0.32 C&I Small Tenant N/A $0.31 $0.19 $0.19 $0.31
C&I Small Owner N/A $0.31 $0.19 $0.19 $0.31
C&I Medium Tenant N/A $0.18 $0.14 $0.14 $0.18
C&I Medium Owner N/A $0.18 $0.14 $0.14 $0.18
C&I Large Tenant N/A $0.16 $0.15 $0.15 $0.16
C&I Large Owner N/A $0.16 $0.15 $0.15 $0.16
2025 Bill Savings ($/kWh)2030 Bill Savings ($/kWh)
S1Continue Current NEMS3BalancedS4Widespread AdoptionNet energy metering at retail rates Net energy metering at retail ratesNet energy billing above avoided costs but below retail ratesS2Targeted LMI MF AdoptionNet energy billing at avoided costsS0 and S5 represent bookend scenarios derived from standalone, simplified back-of-envelope calculations, intended to provide a broad estimate of magnitude. Since these scenarios were not processed through the detailed adoption modeling (RESTORE), they do not include results related to bill savings or utility incentives. 323 of 559

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Customer Storage Bill Savings2025 Bill Savings ($/kWh)2030 Bill Savings ($/kWh) Building Type Ownership
Status
Income
Class S1 S2 S3 S4
Single-Family Tenant LMI $0.00 $0.26 $0.18 $0.00
Single-Family Tenant Non-LMI $0.00 $0.27 $0.20 $0.00
Single-Family Owner LMI $0.00 $0.26 $0.19 $0.00
Single-Family Owner Non-LMI $0.00 $0.28 $0.21 $0.00
Multi-Family Low-Rise Tenant LMI $0.00 $0.08 $0.06 $0.00 Multi-Family Low-Rise Tenant Non-LMI $0.00 $0.24 $0.17 $0.00 Multi-Family Low-Rise Owner LMI $0.00 $0.10 $0.07 $0.00 Multi-Family Low-Rise Owner Non-LMI $0.00 $0.24 $0.17 $0.00 Multi-Family High-RiseTenant LMI $0.00 $0.08 $0.06 $0.00 Multi-Family High-RiseTenant Non-LMI $0.00 $0.24 $0.17 $0.00 Multi-Family High-RiseOwner LMI $0.00 $0.10 $0.07 $0.00 Multi-Family High-RiseOwner Non-LMI $0.00 $0.26 $0.19 $0.00 C&I Small Tenant N/A $0.00 $0.25 $0.25 $0.00
C&I Small Owner N/A $0.00 $0.25 $0.25 $0.00
C&I Medium Tenant N/A $0.00 $0.14 $0.14 $0.00
C&I Medium Owner N/A $0.00 $0.14 $0.14 $0.00
C&I Large Tenant N/A $0.00 $0.12 $0.12 $0.00
C&I Large Owner N/A $0.00 $0.10 $0.10 $0.00
Building Type Ownership
Status
Income
Class S1 S2 S3 S4
Single-Family Tenant LMI $0.00 $0.26 $0.19 $0.00
Single-Family Tenant Non-LMI $0.00 $0.28 $0.21 $0.00
Single-Family Owner LMI $0.00 $0.27 $0.19 $0.00
Single-Family Owner Non-LMI $0.00 $0.29 $0.21 $0.00
Multi-Family Low-Rise Tenant LMI $0.00 $0.05 $0.03 $0.00 Multi-Family Low-Rise Tenant Non-LMI $0.00 $0.23 $0.16 $0.00 Multi-Family Low-Rise Owner LMI $0.00 $0.08 $0.05 $0.00 Multi-Family Low-Rise Owner Non-LMI $0.00 $0.24 $0.16 $0.00 Multi-Family High-RiseTenant LMI $0.00 $0.04 $0.03 $0.00 Multi-Family High-RiseTenant Non-LMI $0.00 $0.24 $0.17 $0.00 Multi-Family High-RiseOwner LMI $0.00 $0.07 $0.05 $0.00 Multi-Family High-RiseOwner Non-LMI $0.00 $0.24 $0.17 $0.00 C&I Small Tenant N/A $0.00 $0.26 $0.26 $0.00
C&I Small Owner N/A $0.00 $0.26 $0.26 $0.00
C&I Medium Tenant N/A $0.00 $0.13 $0.13 $0.00
C&I Medium Owner N/A $0.00 $0.13 $0.13 $0.00
C&I Large Tenant N/A $0.00 $0.10 $0.10 $0.00
C&I Large Owner N/A $0.00 $0.07 $0.07 $0.00
S1Continue Current NEMS3BalancedS4Widespread AdoptionNet energy metering at retail rates Net energy metering at retail ratesNet energy billing above avoided costs but below retail ratesS2Targeted LMI MF AdoptionNet energy billing at avoided costsS0 and S5 represent bookend scenarios derived from standalone, simplified back-of-envelope calculations, intended to provide a broad estimate of magnitude. Since these scenarios were not processed through the detailed adoption modeling (RESTORE), they do not include results related to bill savings or utility incentives. 324 of 559

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Customer Solar Utility Incentives2025 Utility Incentive ($/W)2030 Utility Incentive ($/W) Building Type Ownership
Status
Income
Class S1 S2 S3 S4
Single-Family Tenant LMI $0.00 $0.00 $0.00 $0.00
Single-Family Tenant Non-LMI $0.00 $0.00 $0.00 $0.00
Single-Family Owner LMI $0.00 $0.00 $0.00 $0.00
Single-Family Owner Non-LMI $0.00 $0.00 $0.00 $0.00
Multi-Family Low-Rise Tenant LMI $0.00 $2.59 $1.36 $1.20 Multi-Family Low-Rise Tenant Non-LMI $0.00 $0.00 $0.00 $1.18 Multi-Family Low-Rise Owner LMI $0.00 $2.59 $1.48 $1.18 Multi-Family Low-Rise Owner Non-LMI $0.00 $0.00 $0.00 $1.13 Multi-Family High-RiseTenant LMI $0.00 $2.60 $1.34 $1.20 Multi-Family High-RiseTenant Non-LMI $0.00 $0.00 $0.00 $1.17 Multi-Family High-RiseOwner LMI $0.00 $2.59 $1.42 $1.19 Multi-Family High-RiseOwner Non-LMI $0.00 $0.00 $0.00 $1.02 C&I Small Tenant N/A $0.00 $0.00 $0.00 $0.00
C&I Small Owner N/A $0.00 $0.00 $0.00 $0.00
C&I Medium Tenant N/A $0.00 $0.00 $0.00 $0.00
C&I Medium Owner N/A $0.00 $0.00 $0.00 $0.00
C&I Large Tenant N/A $0.00 $0.00 $0.00 $0.00
C&I Large Owner N/A $0.00 $0.00 $0.00 $0.00
Building Type Ownership
Status
Income
Class S1 S2 S3 S4
Single-Family Tenant LMI $0.00 $0.00 $0.00 $0.00
Single-Family Tenant Non-LMI $0.00 $0.00 $0.00 $0.00
Single-Family Owner LMI $0.00 $0.00 $0.00 $0.00
Single-Family Owner Non-LMI $0.00 $0.00 $0.00 $0.00
Multi-Family Low-Rise Tenant LMI $0.00 $2.28 $0.72 $0.59 Multi-Family Low-Rise Tenant Non-LMI $0.00 $0.00 $0.00 $0.56 Multi-Family Low-Rise Owner LMI $0.00 $2.28 $0.84 $0.56 Multi-Family Low-Rise Owner Non-LMI $0.00 $0.00 $0.00 $0.51 Multi-Family High-RiseTenant LMI $0.00 $2.29 $0.69 $0.59 Multi-Family High-RiseTenant Non-LMI $0.00 $0.00 $0.00 $0.55 Multi-Family High-RiseOwner LMI $0.00 $2.28 $0.77 $0.58 Multi-Family High-RiseOwner Non-LMI $0.00 $0.00 $0.00 $0.37 C&I Small Tenant N/A $0.00 $0.00 $0.00 $0.00
C&I Small Owner N/A $0.00 $0.00 $0.00 $0.00
C&I Medium Tenant N/A $0.00 $0.00 $0.00 $0.00
C&I Medium Owner N/A $0.00 $0.00 $0.00 $0.00
C&I Large Tenant N/A $0.00 $0.00 $0.00 $0.00
C&I Large Owner N/A $0.00 $0.00 $0.00 $0.00
S1Continue Current NEMS3BalancedS4Widespread AdoptionNo utility incentives Guaranteed 5-yr payback for all MF customersGuaranteed 7-yr payback for all MF LMI customersS2Targeted LMI MF AdoptionDirect install for all MF LMI customersS0 and S5 represent bookend scenarios derived from standalone, simplified back-of-envelope calculations, intended to provide a broad estimate of magnitude. Since these scenarios were not processed through the detailed adoption modeling (RESTORE), they do not include results related to bill savings or utility incentives. 325 of 559

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Customer Storage Utility Incentives
2025 Utility Incentive ($/W)2030 Utility Incentive ($/W)Building Type Ownership Status
Income
Class S1 S2 S3 S4
Single-Family Tenant LMI $0.00 $0.00 $0.00 $0.00
Single-Family Tenant Non-LMI $0.00 $0.00 $0.00 $0.00
Single-Family Owner LMI $0.00 $0.00 $0.00 $0.00
Single-Family Owner Non-LMI $0.00 $0.00 $0.00 $0.00
Multi-Family Low-Rise Tenant LMI $0.00 $1.65 $1.50 $1.72 Multi-Family Low-Rise Tenant Non-LMI $0.00 $0.00 $0.00 $1.72 Multi-Family Low-Rise Owner LMI $0.00 $1.65 $1.46 $1.75 Multi-Family Low-Rise Owner Non-LMI $0.00 $0.00 $0.00 $1.72 Multi-Family High-RiseTenant LMI $0.00 $1.65 $1.50 $1.72 Multi-Family High-RiseTenant Non-LMI $0.00 $0.00 $0.00 $1.72 Multi-Family High-RiseOwner LMI $0.00 $1.65 $1.46 $1.73 Multi-Family High-RiseOwner Non-LMI $0.00 $0.00 $0.00 $1.73 C&I Small Tenant N/A $0.00 $0.00 $0.00 $0.00
C&I Small Owner N/A $0.00 $0.00 $0.00 $0.00
C&I Medium Tenant N/A $0.00 $0.00 $0.00 $0.00
C&I Medium Owner N/A $0.00 $0.00 $0.00 $0.00
C&I Large Tenant N/A $0.00 $0.00 $0.00 $0.00
C&I Large Owner N/A $0.00 $0.00 $0.00 $0.00
Building Type Ownership
Status
Income
Class S1 S2 S3 S4
Single-Family Tenant LMI $0.00 $0.00 $0.00 $0.00
Single-Family Tenant Non-LMI $0.00 $0.00 $0.00 $0.00
Single-Family Owner LMI $0.00 $0.00 $0.00 $0.00
Single-Family Owner Non-LMI $0.00 $0.00 $0.00 $0.00
Multi-Family Low-Rise Tenant LMI $0.00 $1.58 $1.49 $1.67 Multi-Family Low-Rise Tenant Non-LMI $0.00 $0.00 $0.00 $1.67 Multi-Family Low-Rise Owner LMI $0.00 $1.58 $1.43 $1.71 Multi-Family Low-Rise Owner Non-LMI $0.00 $0.00 $0.00 $1.67 Multi-Family High-RiseTenant LMI $0.00 $1.58 $1.49 $1.67 Multi-Family High-RiseTenant Non-LMI $0.00 $0.00 $0.00 $1.67 Multi-Family High-RiseOwner LMI $0.00 $1.58 $1.44 $1.68 Multi-Family High-RiseOwner Non-LMI $0.00 $0.00 $0.00 $1.69 C&I Small Tenant N/A $0.00 $0.00 $0.00 $0.00
C&I Small Owner N/A $0.00 $0.00 $0.00 $0.00
C&I Medium Tenant N/A $0.00 $0.00 $0.00 $0.00
C&I Medium Owner N/A $0.00 $0.00 $0.00 $0.00
C&I Large Tenant N/A $0.00 $0.00 $0.00 $0.00
C&I Large Owner N/A $0.00 $0.00 $0.00 $0.00
S1Continue Current NEMS3BalancedS4Widespread AdoptionNo utility incentives Guaranteed 5-yr payback for all MF customersGuaranteed 7-yr payback for all MF LMI customersS2Targeted LMI MF AdoptionDirect install for all MF LMI customersS0 and S5 represent bookend scenarios derived from standalone, simplified back-of-envelope calculations, intended to provide a broad estimate of magnitude. Since these scenarios were not processed through the detailed adoption modeling (RESTORE), they do not include results related to bill savings or utility incentives. 326 of 559

Section 7.7Detailed Model Results: Other DER Technologies 327 of 559

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ÊFor this study, E3 modeled a single adoption scenario for electric vehicles (EVs), demand response (DR), and energy efficiency (EE) based on information from GWP’s IRPÊThese adoption forecast estimates were presented with a range in downstream analysis to account for uncertainties that were not fully addressed Key Results: Adoption Forecast for Other DERs (MW)
29 43
56 67
77 88
99 0
20 40
60 80
100
120
2024 2025 2026 2027 2028 2029 2030
Cumulative DER Capacity (MW)
Demand Response
Energy Efficiency
LDEV Managed Charging (V1G)
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ÊFor the purposes of this study, the DR adoption forecast was based on GWP’s current plan of a 4-year residential and commercial DR program •A four-year residential and commercial DR program with an online marketplace that aims to deliver up to 10 MW of load reduction during DR events by the end of the program term•At the end of FY 2022-2023, a total of 2.5 MW was under control, representing 25% of the 4-year program goal Residential & Commercial Demand Response Adoption Forecast GWP Peak Saving Program
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ÊFor the purposes of this study, the EV adoption forecast was derived from the GWP IRP to ensure consistency in analysis assumptionsÊGWP's IRP adopted the CEC's IEPR forecast's general assumptions without any modificationsÊE3 made the following assumptions to approximate nameplate capacity from light-duty EV (LDEV) managed charging•100% Light-duty BEV (LD-BEV)•50% L1 and 50% L2•L1 Charger: 1.4 kW•L2 Charger: 7.2 kW EV Adoption Forecast
In 2021, GWP conducted a Clean Energy Analysis with Ascend Analytics, utilizing the electric vehicle projections provided by the CEC (below) 330 of 559

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ÊFor the purposes of this study, the peak savings forecast for Energy Efficiency was derived from the GWP IRP to ensure consistency in analysis assumptionsÊIn 2021, the California Municipal Utilities Association (CMUA) hired GDS Associates, Inc. to analyze and quantify the potential impact of energy efficiency in CMUA member electric service territoriesÊThe CMUA study serves as the foundation for energy efficiency targets for fiscal years 2022 through 2031, aiming to achieve 17,978 MWh per year in energy savings and 2,860 kW per year in demand response savingsÊThese figures were derived from the 10-year average of the forecasted figures developed by GDS Energy Efficiency Peak Saving Forecast
2022-2031 Forecast•Energy Saving: 17,978 MWh/yr•Peak Saving: 2,860 kW/yr•Assume peak saving already accounts for capacity contributions (i.e., after ELCC adjustment) 331 of 559

Section 8Cost and Benefit Analysis
332 of 559

Section 8.1GWP Benefit-CostAnalysis Approach
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ÊThe CPUC defines “cost-effective” and “cost-effectiveness” as a set of well-defined “cost tests in the California Standard Practice Manual (SPM)”*ÊThese cost tests provide a methodological framework to examine the benefits and costs of a particular measure from different perspectives and have become a standard in many other jurisdictions Cost-Effectiveness and Cost Test Perspectives
Cost Test Primary QuestionPCTParticipant Cost TestNet benefit for customers who adopt solar?RIMRatepayer Impact MeasureWill utility rates increase or decrease?PACTProgram Administrator Cost TestWill utility costs increase or decrease?TRCTotal Resource Cost TestNet benefits to City of Glendale?SCTSocietal Cost TestNet benefit to society as a whole?* California Standard Practice Manual 334 of 559

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ÊJurisdictions have recently faced challenges considering DER cost-effectiveness as the zero GHG emission planning paradigm has emergedÊCauses for challenges for DER cost-effectiveness are:•The cost-effectiveness of many EE/DER programs is decreasing due to increasingly stringent building codes and standards, coupled with declining marginal energy costs•The cost-effectiveness of building electrification can be difficult to achieve given the high upfront costs of appliances•Increased focus on resiliency and equity for local communitiesin driving interest in DERsÊAs a result of these challenges, jurisdictions have developed strategies for DER program evaluations, which have included:•Program Buckets: Create separate categories for market transformation, policy, and equity programs, each with less stringent benefit-cost thresholds•Update Avoided Costs: Adjust to better reflect the decarbonized grid planning paradigm•Consider Additional Benefit Categories: Include societal, community, and non-energy benefits Challenges and Strategies for DER Cost-Effectiveness
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State primary cost tests are shifting away from TRCÊMany states continue to use the TRC as a primary cost test, but fewer than 10 years ago•More states (CT, ME, MD, NH, NJ, RI) are shifting to state-specific costs tests that incorporate elements of the SCT and TRC•Many additional states have modified traditional cost tests to better fit changing needs of electrification and fuel switching (CA, CO, MA, IL, WA, WI)•Some states have multiple primary cost tests (MS, NC, OR, VA) that incorporate TRC along with UCT, PCT, and/or RIM•Not all states have a dedicated primary cost test (AL, AK, NE, ND, SC, WV)ÊSome states use different cost-effectiveness criteria for low-income EE programs Cost-Effectiveness Testing for Energy Efficiency ProgramsDatabase of Screening Practices (National Energy Screening Project, E4TheFuture)Analysis of State Approaches to Cost-Effectiveness Testing 336 of 559

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ÊCurrent types of NEBs included by other jurisdictions:•Monetized: a dollar value per physical unit ofimpact for a specific NEB•Quantitative: metrics for physical units of impacts, but no dollar value•Proxy: a percent or dollar adder to account for unincluded qualitative NEBsÊMost jurisdictions and groups interested in NEBs are working on moving towards quantification as a more precise method of valuing all types of benefitsÊNot all types of cost tests can incorporate NEBs:•TRC: utility and participant NEBs only•SCT: all NEBs, including societal•UCT/PAC, PCT, RIM: no NEBs included Non-Energy Benefit (NEB) Inclusion in Cost Tests
© GeoNames, Microsoft, TomTomPowered by Bing
1 2
3Series1
Database of Screening Practices (National Energy Screening Project, E4TheFuture) QuantitativeProxy (%)Monetized
Participant Non-Energy Benefits in U.S. States
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206
ÊGWP is not subject to the same regulatory requirements as IOUs for DER cost-effectiveness tests. However, demonstrating cost-effectiveness remains valuable for gaining City Council and public support.ÊA benefit-cost analysis can be used to assess the costs and benefits under different perspectives (participants, ratepayers, society) for GWP to achieve its 10% solar and energy storage adoption target.ÊA benefit-cost analysis can be used to inform appropriate incentive levels.•Can inform incentives needed for customers to find DER adoption cost-effective•Can inform the amount of program funding that can prevent or minimize cost-shift to non-participants•Can inform the amount of program funding that can promote societal benefits of DERsÊGiven these use cases for GWP , E3 conducted a benefit-cost analysis under three key perspectives:•Participants (Participant Cost Test, or "PCT")•Ratepayers (Ratepayer Impact Measure, or "RIM")•Society (Societal Cost Test, or "SCT") Applying DER cost-effectiveness challenges from other jurisdictions to GWP’s adoption targets 338 of 559

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Benefit-Cost Analysis Approach
E3 conducted a benefit-cost analysis for several representative GWP customer types Results for individual representative customers were scaled up according to their share of GWP DER adoption, providing cost-effectiveness results for GWP's entire service territory The analysis covers various scenarios that reflect GWP's implementation of different programs and incentives for DER adoption The benefit-cost analysis assumes that GWP will introduce programs and/or incentives at the start of 2025 and evaluates all systems adopted from 2024 to 2030 E3 concentrated the analysis on solar and solar + storage systems, as these are the primary DER resources relevant for adoption target compliance Building Types•Single-Family•Low-Rise Multi-Family•High-Rise Multi-Family•Small C&I•Medium C&I•Large C&IIncome Classes•Low- to Moderate-Income (LMI)•Non-LMI (general market)Resiliency Values•Base resiliency value•High resiliency value 339 of 559

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Benefits and Costs Components by Cost Test Perspective
ComponentParticipant Cost Test (PCT)Ratepayer Impact Measure (RIM)Societal Cost Test (SCT)Bill Savings+–Upfront Costs– –Fixed Operations and Maintenance Costs– –Federal and State Incentives+ +GWP Incentives+–Utility Avoided Costs++Resiliency Benefits+Additional Societal Benefits + N/ACostBenefitNote: Administrative costs were not included in the cost tests. When interpreting the results, please consider these additional costs from both the ratepayer and administrator perspectives to ensure that all program implementation expenses are fully accounted for.

Encouraging Customer Adoption
Realizing Value for Grid & CommunityManaging Cost-Shift & Affordability Participant Cost Test
Ratepayer Cost TestSocietal Cost Test
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Section 8.2GWP Benefit-CostAnalysis Inputs & Assumptions 341 of 559

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ÊUpfront costs for rooftop solar and behind-the-meter (BTM) storage systems were calculated based on the system sizes for each customer segment. These costs were used to determine the total upfront cost for system installations.ÊThe values used in this calculation were derived from RECOST, E3's internal resource pricing model, which incorporates inputs from various sources. For this study, the NREL ATB version used in RECOST was ATB 2023.

Benefit-CostAnalysis Inputs: Upfront Costs
E3 RECOST
Technology Cost Assumptions Sources: NREL, LBNL, Market DataTechnology Financing Assumptions Sources: NREL, Market Data Technology Operations Assumptions Sources: NREL, LBNL
Inputs (Database)Outputs (Calculations)
Discounted Cash Flow ModelOutputs: NPV, IRR
Levelized CostsOutputs: LFC, LCOEResults Validation
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ÊFederal and state incentives were used to offset the upfront costs of solar and storage installations. These were applied prior to any additional GWP incentives. ÊIn scenarios with GWP direct install, incentives were assumed to still apply, leaving GWP to pay the difference between the full upfront cost and the applicable incentives.

Benefit-CostAnalysis Inputs: Federal and State Incentives Discount NameJurisdictionAmountTimelineApplicable TechnologiesSolar Investment Tax Credit (ITC)Federal30%30% expires in 2026, ITC is reduced to 22% in later years Solar and/or storageSelf-Generation Incentive Program (SGIP)California$0.45/W as a general approximation2024 and 2025 onlyStorage only, not including new buildings 343 of 559

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ÊLBNL’s Interruption Cost Estimate Calculator (ICE Calculator) uses user inputs to calculate the $ per kWh of lost load•Number of Customers: GWP 2024 IRP•SAIDI and SAIFI: EIA-861Ê$ per kWh of lost load was converted to $ per total kWh annual load by multiplying by the probability of an outage in each minute•Solar and storage gets the full value since it is assumed that a BTM solarand storage system would eliminate the number of outages per year to 0•Solar-only systems get no resiliency valueÊFor this study, E3 developed sensitivities around resiliency values:•Base Resiliency: default assumption in final analysis•High Resiliency: applies a 10x multiplier to the base resiliency values Benefit-CostAnalysis Inputs: Societal Benefits - Customer Resiliency Value Source: LBNL Interruption Cost Estimate Calculator
Source: US Energy Information Administration, EIA-861 File 344 of 559

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ÊThe Social Cost of Carbon (SCC) represents the net value to society of increasing or reducing carbon dioxide levels•The SCC is based on monetizing damages incurred by temperate changes, sea level rise, and CO2 concentrations as a product of increased emissionsÊSocial Cost of Carbon is calculated using the EPA’s 2022 “External Review Draft of Report on the Social Cost of Greenhouse Gases”•The 2.0% discount rate option was selected as a mid-optionÊThis value was converted to nominal dollars using historical and forward-looking inflation rates. It was then multiplied by the amount of CO2e avoided by solar and storage to calculate the final value.

Benefit-CostAnalysis Inputs: Societal Benefits - Social Costs of Carbon Table ES.1: Estimates of the Social Cost of Greenhouse Gases (SC-GHG), 2020-2080 (2020 dollars),link to source. 345 of 559

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ÊImpacts of emissions on human health were calculated using the statewide Air Quality Adder (AQA). This value is recognized by the CPUC for the state societal cost test. ÊThe AQA value of $14/MWh of avoided gas generation was determined by the state-of-the-art air quality modeling done for the IDER proceeding in 2020/2021.ÊAlthough the actual impact varies by region, the CPUC uses a single statewide value. •Gas units may need to run for local reliability where impact is highest due to existing air quality concerns, weather patterns, and high population density (e.g., LA Basin). •E3 was unable to calculate a more spatially granular value within this scope of work.

Benefit-CostAnalysis Inputs: Societal Benefits - Air Quality Adder (AQA) Monetized Health Impact of Gas Generation by Location
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Calculated using internal assumptions about capacity factors of rooftop and utility-scale solar and the assumed replacement resource of rooftop solar from the avoided costs workstream Benefit-CostAnalysis Inputs: Societal Benefits - Land Use Impacts Acres of Desert Preserved
MW of Utility Scale Solar Avoided
MW of Utility-Scale Solar
$ Value of Desert Ecosystem Services
Acre of Desert Preserved
Value of Avoided Utility Scale Solar Land Use
Calculated using NREL research on single-axis large solarCalculated using research from Chen and Costanza (2024) that includes potential ecosystem benefits such as raw material provisioning, surface water value, soil fertility, and generic diversity Final calculated value is $3,768/MW-year of rooftop solar installed (in $2024) Only solar-related
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ÊThese additional inputs were run through RESTORE, E3’s internal adoption and impact analysis model, to create bill savings, avoided costs, and emissions impacts of various levels of solar and storage adoption Benefit-CostAnalysis Inputs: Additional InputsInput SourceCustomer loadsBuilding load shapes from NREL’s ResStock and ComStock modelsSolar generation profilesLocalized solar profiles from NREL’s PVWatts modelSolar and storage system sizingInternal DER potential and market segmentation analysisRetail ratesGWP’s latest residential and commercial retail rates, pulled from the GWP websiteStorage dispatch scheduleSimulated by E3’s RESTORE model in the adoption and impact analysis 348 of 559

Section 8.3GWP Benefit-CostAnalysis Key Results
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ÊParticipant benefits include bill savings, federal and GWP incentives, and resiliency benefitsÊParticipant costs include upfront costs, maintenancecosts, and interconnection fees Participant Perspective (PCT)Net Present Value of Per Customer Costs and Benefits Single-family customer adopting solar in 2025Single-family customer adopting solar + storage in 2025 S1: Continue Current NEMS2: Targeted LMI AdoptionS3: BalancedS4: Widespread Adoption Resiliency BenefitsFederal and State IncentivesBill Savings Fixed O+MUpfront Costs S1: Continue Current NEMS2: Targeted LMI AdoptionS3: BalancedS4: Widespread Adoption ÊIn all scenarios, solar and solar + storage provide net benefits over the system's lifetimeÊDriven by high bill savings under various billing mechanisms, even under net billingÊDespite lifetime savings, high upfront costs of solar and solar + storage may still pose barriers to adoption 350 of 559

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Perspective of All GWP Ratepayers (RIM)(Participants + Non-Participants) S1: Continue Current NEMS2: Targeted LMI AdoptionS3: BalancedS4: Widespread Adoption GWP IncentivesBill Savings Utility Avoided Costs
ÊLifetime costs and benefits for compensating new solar and storage adopters from 2024 to 2030ÊDetermined by the number of adopters, net metering/billing compensation level, and the level of additional utility incentives provided ÊPredictably, all scenarios have net ratepayer costs that increase GWP rates in order to accelerate DER adoption Total Glendale Ratepayer Costs and BenefitsFor Solar and Solar + Storage Systems Adopted in 2024-2030 351 of 559

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ÊThe societal perspective captures benefits that accrue to society at large •Societal benefits include federal incentives, GWP avoided costs, and other societal benefits that can be monetized including reduced land use, air quality impacts, and reduced emissions•Societal costs include upfront system costs and maintenance costs Total Glendale Societal Costs and BenefitsFor Solar and Solar + Storage Systems Adopted 2024-2030ÊBenefits or costs transferred within the boundaries of Glendale are not included•For example, customer bill savings offered by GWP are not includedÊSolar and solar + storage provide net benefits to society across all scenarios•Net benefits are driven by avoided utility costs and avoided CO2 emissionsS1: Continue Current NEMS2: Targeted MF LMI AdoptionS3: BalancedS4: Widespread Adoption Societal BenefitsUtility Avoided CostsFederal and State Incentives Fixed O+MUpfront Costs Glendale Societal Perspective (SCT)
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Economic Analysis of Scenarios: Cost Test Scores
S1Continue Current NEMS2Targeted LMI/MF AdoptionS3BalancedS4Widespread Adoption Participant Cost Test

2.252.163.04

3.04 Ratepayer Impact Measure

0.280.450.390.29
Societal Cost Test

1.872.092.112.17
𝐵𝑒𝑛𝑒𝑓𝑖𝑡𝑠𝐶𝑜𝑠𝑡𝑠≥1.0
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ÊAll scenarios have annual net ratepayer costs that increase GWP rates due to accelerating DER adoption Annual Net Ratepayer Costs
Annual Net Ratepayer Costs ($)Reference Scenario (S0)Range of Scenario Results (S1-S4)Continue Current NEM (S1) $-
$20
$40
$60
$80
$100
$120
2024
2026
2028
2030
2032
2034
2036
2038
2040
2042
2044
2046
2048
2050
2052
2054
Millions
S1 Net Ratepayer Costs
S2 Net Ratepayer Costs
S3 Net Ratepayer Costs
S4 Net Ratepayer Costs
$-
$20
$40
$60
$80
$100
$120
2024
2026
2028
2030
2032
2034
2036
2038
2040
2042
2044
2046
2048
2050
2052
2054
Millions
S1 Net Ratepayer Costs
S2 Net Ratepayer Costs
S3 Net Ratepayer Costs
S4 Net Ratepayer Costs
S4
S2S3S1
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ÊAcross the scenarios 1 through 4, rates are anticipated to increase between 6% and 11% due to solar and storage programs on top of other anticipated sources of rate growthÊThis means that the average low- or moderate-income (LMI) customer will now be paying between $4 and $6 more per month on electricity, or $48 to $72 per year Retail Rate and Customer Bill Impacts
$-
$10
$20
$30
$40
$50
$60
$70
$80
2023 2025 2030
0%
2%
4%
6%
8%
10%
12%
2023 2025 2030
11%
6%
+$6+$4Range of Scenario Results (S1-S4)
Range of Scenario Results (S1
-S4)
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Section 9Potential Program and Policy Options
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Section 9.1 Overview
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ÊProgram proposals ranked by overall qualitative performanceÊReasonable DER compensation levels that mitigate cost shifts are preferred Qualitative screening analysis prioritizes program and policy options crucial for achieving City Council targets over othersPriority Level 358 of 559

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ÊIn addition to adoption impact modeling, which captures prioritized programs and policies, the following potential program design options are presented for prioritized programs Potential Program and Policy Options
Outreach Education & SupportStreamline & Improve Permitting ProcessNet Metering vs. Net Billing Incentive DesignFor example, upfront/base rebates, performance-based incentivesFeed-in Tariff (FiT)Solutions for Renter and LMI CustomersFor example, community solar, virtual solar 359 of 559

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Equity and Justice Concerns Within DER Adoption
Distributional
Procedural
Recognition
Many customers face already high bills, some are prohibitively high. How can utilities create programs and policies that do not increase rates for non-participants? How can utilities ensure energy affordability for all customers? Not all customers receive equal treatment from the electric grid. Some customers see more frequent outages than others. How can utilities work to repair this injustice with DERs that can provide resiliency benefits? Historically, some solar and storage programs have seen a disproportionate number of incentives going to high-income customers. How can utilities ensure that incentives are aligned with those who need them most? Most solar- and storage-adopting customers across Glendale and the United States are high income homeowners. How can utilities ensure that LMI renters are also eligible for technologies that produce bill savings? Not all customers know about available programs. How can utilities spread knowledge about programs to those who need them most? Involving all types of customers in decision-making and planning yields more equitable policies. How can utilities highlight marginalized voices in the decision-making process? 360 of 559

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ÊUnder traditional NEM programs, a landlord would pay upfront solar and storage costs, but tenants would see the bill-savings benefits. This “split incentive” problem has led to much lower solar and storage adoption rates for renters than homeowners. Solutions to the “split incentive” problem focus on allowing customers to gradually pay back the upfront costs of solar or storage.

Providing Access for Renter and LMI Customers
Solar or Storage LeaseCustomers pay a monthly fee for solar panels or storage to be installed on their roof.

Community SolarCustomers subscribe to a share of a larger solar installation and pay a monthly fee to receive bill savings.

Virtual SolarCustomers in multi-unit buildings can subscribe to a shared solar installation.

On-Bill FinancingUtility pays the upfront costs, which are then recovered on customer bills.

Green RatesCustomers pay a higher electricity rate to opt for 100% clean energy.

ÊSome, but not all, of these programs also allow customers without roof space (i.e., apartments and condos) to adopt solar and storage. 361 of 559

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For solar, multiple types of programs could exist in Glendale Net Energy Metering (NEM)Individual customers install solar or storage in their own buildings.

Virtual SolarCustomers in multi-unit buildings share a single solar and storage installation across all units.

Community Solar (CS)Customers subscribe to a share of an off-site larger solar installation. 362 of 559

Section 9.2Program Deep Dive: Incentive Design
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Incentive design can be diverse and can be used to encourage beneficial behaviors High incentives in the near term and lower incentives in later years could encourage early adoption.

Apart from performance-based incentives, upfront incentives can also be offered in exchange for optimal storage dispatch.

Additional incentives for bundling solar and storage installations could be used to increase storage adoption.

Explore including tax abatements (e.g., property tax) such as NYC's property tax abatement for solar and storage.

Explore the possibility of direct install programs for multifamily, low- and moderate-income, or disadvantaged communities.

Utilize state and federal level support to help residents secure the California Self-Generation Incentive Program (SGIP) incentives through SoCalGas, considering that most Glendale residents might use their gas service.

Consider alternative funding mechanisms or sources that mitigate the burden to low-income and disadvantaged communities (e.g. , property tax or Income Graduated Fixed Charges). 364 of 559

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Encouraging customers to dispatch storage for grid needs increases community benefits Flat Rate
Flat Rate
Solar Generation

ILLUSTRATIVE
No Storage Charge/Discharge in Normal Days
ÊCustomer-owned storage used for back-up power or bill reductions provides little or no benefit for the Glendale community Solar
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ÊPrograms that provide price signals to customer-owned storage for a limited number of hours in the year can increase community benefits substantially Encouraging customers to dispatch storage for grid needs increases community benefits Utility Signal
Dispatch Signal
Solar Generation
Storage Charge
Storage Discharge

ILLUSTRATIVE
Solar
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Additional incentives lessen costs for DER adoption•Additional incentives from GWP would allow customers to install solar and storage at lower costs, mitigating the upfront cost barrier or improving lifetime investment return.•These incentives could be partial upfront/base rebates, full direct install programs, or performance-based incentives that encourage customers to dispatch battery storage for grid needs and increase community benefits.•These incentives could be offered to all residents or targeted at specific types of customers, such as low-income multi-family apartment buildings.•The City of Glendale offered incentives for solar in the past, but they have been phased out.

Benefits: •Reducing the cost to install solar and storage increases access for low- and moderate- income customers.•Reductions in upfront costs and improved lifetime investment return increase adoption across all customers.

Possible Concerns:
•Upfront incentives alone cannot solve physical and technical constraints faced by many renters and condo owners, and performance-based incentives might require additional tele-communication technology support.•High incentives increase the revenue that GWP recovers, which in turn increases rates.•Restarting the incentive program may pose an issue for customers who did not receive the incentive between the end of the old program and the beginning of the new program. 367 of 559

Section 9.3Program Deep Dive: Rooftop Solar Compensation 368 of 559

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Glendale’s Current Approach to Solar CompensationGlendale uses Net Energy Metering (NEM) to compensate customers for their rooftop solar. This tariff is called the “Customer Owned Generation” tariff.•Under NEM, solar exports and self-consumption are compensated at the exact value of solar imports.•This type of policy, like the CPUC’s NEM 1.0, has high compensation values and creates a strong incentive for customers to adopt solar.•NEM leads to a significant cost shift since solar exports and self-consumption are compensated above the avoided cost of the utility not having to procure that energy.The “Customer Owned Generation” tariff is capped at 5% of GWP’s total peak demand.•The tariff is first-come, first-serve for customers.GWP caps large solar systems (<10kW) at 110% of annual load or 1 MW-AC.

Very few customers in Glendale (<2%) are subscribed to time-of-use (TOU) rates.•GWP has faced technical difficulties installing electric meters compatible with TOU rates.<2%110%5% NEM 1.0
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Rooftop solar can be compensated by the utility in many different ways TariffSelf-ConsumptionExports Bill SavingsCost ShiftNet Energy Metering (NEM)All generation (both self-consumption and exports) credited at the customer’s import rate ++++++Net Billing (NEB)Self-consumption credited at the import rateExports credited at a reduced export rate++++Buy-All, Sell-All(BA, SA)All generation (both self-consumption and exports) credited at a reduced export rate ++ Note: “Net Metering / NEM” is often used erroneously/colloquially to describe all tariffs for crediting exports from customer-generators Self-consumption3,000 kWh/yrImports4,500 kWh/yr
Exports4,500 kWh/yr
7,500kWh total consumption7,500kWh total generation
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Options for Program Improvements: Rooftop Solar Compensation Compensation RatesShift solar and storage compensation to a net billing tariff structure.Align export compensation with GWP avoided costs.Require TOU rates for solar and storage program enrollment.

Program Sizing ConstraintsExpand total program size by allowing more customers to be subscribed to the customer generation tariff.Relax constraints on system sizing.

Section 9.4Program Deep Dive: Virtual Solar
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Virtual solar allows building owners to share solar and storage credits with multiple units•Virtual solar creates an economic, but not necessarily physical, connection between multiple units within a single building. •This type of program is modeled after the California Public Utility Commission's VNEM program but could be implemented in many different ways.

Benefits: •Virtual solar allows renters and apartment owners who cannot install solar or storage on shared roofs to access the benefits of solar and storage.•Upfront customer costs may be lower than single-unit solar installations due to economies of scale.

Possible Concerns: •Property owners may require high compensation or incentives to consider installing virtual solar. •The utility's billing could be complicated. 373 of 559

Section 9.5Program Deep Dive: Community Solar
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ÊEnabling customer choice and providing a “green” or “clean” option to ultimately reduce low-to-moderate income (LMI) customer energy burdens is the key driving force behind state- and federal-level policy action à 10-30% bill reductions are the target•Federal policy has taken the form of large incentives for community solar installations via the 2022 Inflation Reduction Act–LMI Bonus Credits (10% ITC bonus for siting in LMI communities and an additional 20% ITC bonus for directly serving LMI customers) for up to 1.8 GW-DC of installations in 2023 and 2024•Results in up to 50% ITC benefits–Interconnection costs included in ITC for under 5 MW projects–$7B in state funds to create/expand distributed solar programs•State policy actions have been broader and more diverse in terms of scale/scope ranging from small pilots to large multi-GW/$billion programs–Explicit trade-offs and competing interests between providing distributed solar access to underserved communities like LMI and/or renters at least cost vs. creating a robust “market” for non-utility electricity providers like 3rd party community solar developers/owners Avoiding high rates/bills, especially for low- to-moderate income customers, is a driving force for policy action 375 of 559

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Design choices vary by state but follow common archetypes Asset Ownership
Customer Compensation
Enrollment
Program Size
Project Eligibility
Nationally, capacity roughly split between utility and third-party ownership Typically mirrors retail rate structure and compensation for exported solar, which vary from state to state Generally, all customers are eligible, with minimum/maximum subscription levels placed on C&I and residential customers New programs often start with targets around 100-200 MW; mature programs are reaching scales in excess of 1,000 MW Most programs have a cap on project size between 1-5 MW and allow solar only; hybrid projects still uncommon unless required 376 of 559

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ÊTwo prevailing models for ownership of community solar facilities:•Third-party ownership:a third party (developer, retail electric provider)builds, owns, and operates the array and enrolls/manages customers•Utility ownership: The utilityowns the solar arrayand sells portions of the project to customers, who receive monthly bill creditsÊUtilities often purchase projects that have been developed by third parties via build-own-transfer agreements•In some cases, utilities market to customers while third parties retain ownershipÊPreferred ownership structures vary from state to state; in some cases, states have used hybrid models for ownership Common Community Solar Ownership and CompensationÊAsset owner is typically responsible for enrollment and contracting with customers •Customers pay either subscription or energy charges and receive credits towards their electricity bills•Different mechanisms are used for customer bill offsetsÊCredit value calculations vary by state:•Value of solar: credits based on administratively determined “value of solar” calculations•Full retail rate: customers’ bill credits offset kWh consumed on a 1:1 basis•Discounted retail rate: customers’ bill credits offset kWh consumed on a discounted basis•Other: negotiated and/or competitively determined rate•Additional incentive value “adders” possibleÊREC ownership varies based on program design 377 of 559

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Program EnrollmentsPrograms typically require a share to be contracted with residential/low to moderate-income (LMI) customersPrograms may have limits on shares allocated to individual C&I customersDevelopers often use subscription management companies to market and manage customer operations Program SizeProgram sizes range from 50 MW to GW+ in more mature markets Programs often begin around 100-200 MW but very much depends on the potential size of the marketVoluntary markets (those without policy directives) do not have program limitations Project EligibilityProject sizes in programs across the U.S. are typically five MW or lessSome states have minimum project sizes that are 1-2 MWVoluntary markets do not have size limitations Other elements of community solar program design
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Section 9.6Program Deep Dive: Feed-in-Tariff
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Feed-in-tariffs (FiT) provide economic certainty to developers interested in interconnecting solar or storage in Glendale•A feed-in tariff (FiT) is a guaranteed price for renewable power producers that ensures their long-term compensation. •Unlike NEM, which is focused on sizing solar to serve onsite load, FiTs are designed to allow participants to maximize their site’s solar potential, unlocking properties within city limits that are not eligible for NEM, such as carports and parking canopies. •Examples: LADWP has a FiT program that allows eligible sites to sell energy directly to the utility, rather than using it to offset load. LADWP’s “Carport and Canopy” incentive is a one-time rebate for large parking lot owners.

Benefits: •FiTs have significantly increased investment in renewables in other jurisdictions.•Most developers are unlikely to build resources without a long-term contract in place to guarantee payment for their energy.•FiTs encourage solar and storage development on underutilized surfaces, such as brownfields, landfills, and parking canopies.Possible Concerns: •By entering a contract, Glendale cannot change compensation to align with the market in future years. 380 of 559

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Options for Program Improvements: Feed-in-Tariff
Program Sizing ConstraintsExpand total program size beyond 4.2 MW. Remove the 1.4 MW constraint on system sizing.

Section 9.7Robust Customer Outreach, Education, and Resource Support 382 of 559

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Conduct comprehensive outreach and educational campaigns to enhance awareness and empower residents to make informed decisions with an understanding of the underlying economics Enhance outreach and educational campaigns to improve customer awareness and empower residents Additional outreach on federal and state support (IRA, SGIP , etc.) Proposed adoption programs that use mechanisms that customers intuitively understand Comprehensive outreach and knowledge campaigns from GWP to inform and educate residents: 1) Enhance awareness, 2) Understand costs and benefits, 3) Grasp the economics involved, and 4) Enable informed decision-making 383 of 559

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Examples of improving support and guidance via web resourcesHow to Work with DevelopersSolar and DER BasicsCertified/Approved ContractorsUseful Data EV Electricians List: Provides lists of certified electricians for EV customers.

NYSERDA Approved Contractors
ABP Approved VendorsCalifornia DGStats Database: Includes data for solar NEM/NBT and energy storage interconnection applications within PG&E, SCE, and SDG&E territories, providing valuable starting information for Glendale customers. Check this SCE example.

Battery Storage Guidance: comprehensive webpages providing detailed guidance on battery storage and solar solutions Going Solar Webpage: offers guidance on installing solar, finding contractors, and lists federal and state incentive support 384 of 559

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ÊInformation on solar and battery storage contractors is now available on the GWP website GWP already took actions to improve their resource supportwww.glendaleca.gov/SolarContractors 385 of 559

Section 9.8Improved Permitting, Interconnection, and Approval Process 386 of 559

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ÊA significant volume of permits must be processed in the near term when customers begin installing DERs; this volume has the potential to overwhelm the existing City of Glendale processes.ÊGWP needs a faster, easier, and more scalable permitting, interconnection, and approval process to reduce barriers and constraints to DER adoption.

Automate and simplify the process of installing solar and battery storage Automated review and approval of customer projects can reduce costs and speed up timelines. NREL’s SolarAPP+ is a free software platform offering process automation. GWP has adopted SolarAPP+.Simplify inspection processes with straightforward checklists for residential solar and energy storage permits to avoid delays and extra costs. Virtual inspections can further streamline utility review, permitting, inspection, and interconnection.

Reduce permitting and interconnection fees and provide waivers for low-income customers.

Allow solar systems to be sized for future load growth from electric vehicles and appliances. 387 of 559

Section 9.9On-Bill Financing & Repayment
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ÊOn-bill financing (OBF) and repayment (OBR) are methods where a utility or private lender provides funds for energy efficiency, renewable energy, or other generation projects. Repayment is made through regular charges on the customer's utility bill.•OBF/OBR offers advantages such as low or zero interest rates, straightforward contracts, and easy repayment. •However, these options are only available in areas where utilities offer on-bill programs.

On-Bill Financing/On-Bill Repayment (OBF/OBR)
PG&E requested authorization for an OBF/OBR Pilot starting in March 2021 to support K-12 schools installing clean power projects. The pilot will finance the SGIP-eligible storage components to improve resiliency during power outages: link PG&E Supports Restaurant Business Customers via OBF: PG&E offers 0% interest loans for replacing old and worn-out equipment with more energy-efficient models to qualified non-residential PG&E customers. •PG&E OBF Handbook•Assistance summary Better Buildings, an initiative of the U.S. Department of Energy (DOE), provides a comprehensive guide on OBF/OBR with how it works, procs and cons, state of the market, case studies, and additional resources: link Typical On-Bill Financing or Repayment Structure
Note: Materials in this slide are adapted and customized from Better Buildings Solution Center.

Landlord/Tenants
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ÊOBF/OBR typically targets homeowners, but a well-designed program can also address split incentive issues between landlords and tenants with necessary modifications and customizations.ÊTo increase access for renters, project costs and incentives in the form of electric bill savings could accrue to both landlords and tenants to provide proper incentive signals. ÊHere is one conceptual program framework:

Expanding and customizing OBF/OBR to address split incentive issues for landlords and tenants Example OBF/OBR Scheme for Rental Unit(s)
•Adopted and customized from Bird, S., & Hernández, D. (2012). Policy options for the split incentive: Increasing energy efficiency for low-income renters. Energy Policy, 48, 506-514. https://doi.org/10.1016/j.enpol.2012.05.053 As part of the agreement, tenants are responsible for covering the loan payments and can benefit from savings on their energy bills. A net monthly saving for tenants can reduce tenants' energy costs while supporting their transition to cleaner energy sources.Provide small financial incentives to landlords to offset the costs associated with managing and overseeing the upgrade process, thereby encouraging their active participation.•For example, a small portion of the tenant's monthly bill savings can be shared with landlords in the form of a small monthly payment on the tenant’s utility bill for the first five years, which would help reinforce and make tangible the benefits of participating in the program for landlords. 390 of 559

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More Information on Basic and Contract Structure AttributesÊProject Type: which project types can be financed using this option?ÊApplicable Sectors: which customer sector does it commonly serve?ÊGeographic Scope: is it available throughout the U.S. or only in limited areas with supporting policies?ÊBuilding Ownership: does it work well for leased, owned, or both?ÊTypical Project Size: what range of project sizes does it commonly serve?ÊContract Complexity: how complex is it from the customer's perspective?ÊParties Involved: what type of organizations are typically involved in executing this option?ÊPayment Type: are customer payments fixed over time or typically variable? Overview of Typical OBF/OBR Structure
Note: Materials in this slide are adapted and customized from “On-Bill At-A-Glance” in Better Buildings Solution Center. 391 of 559

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Overview of Policy Responses to the Split Incentive Problem •Adopted and reformatted from Bird, S., & Hernández, D. (2012). Policy options for the split incentive: Increasing energy efficiency for low-income renters. Energy Policy, 48, 506-514. https://doi.org/10.1016/j.enpol.2012.05.053 ContractsRegulationAll-in Services
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Section 10Discussion
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ÊScenarios are shaped by stakeholder input, policy directives, and GWP’s goals. Each scenario’s proposed program portfolio was evaluated based on how effectively it addresses these values from various perspectives.ÊContinuing the current NEM structure may lead to higher costs. However, a strategically planned program and incentive portfolio could drive greater solar and storage adoption, improve distributional equity, and reduce ratepayers' costs.

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Clarifications on how to correctly interpret the City Council’s adoption targets are necessaryAt least 10% of GWP customers adopt solar and energy storage systems by 202710% adoption target for solar + storage systems vs. 10% for either solar or solar + storage systems? Develop additional demand management measures, with a minimum total peak dispatchable and peak-load-reducing capacity of 100 MW Which systems qualify?
Standalone SolarSolar + StorageStandalone Storage
100 MW nameplate or effective capacity?
Nameplate CapacityEffective CapacityVS.
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1.Rooftop solar owned, financed, or leased by single-family customers (one system for one electric customer)2.Rooftop solar owned, financed, or leased by multi-family property owners/managers under virtual net metering programs and shared among tenants and unit owners (one system for multiple electric customers)3.Subscribers of off-site solar solutions like community solar, solar share, and green rate options (one project for numerous electric customers)All options must be carefully evaluated for cost-effectiveness against other solar solutions, particularly lower-cost utility-scale city-owned options.

Can GWP reach 10% customer solar adoption by 2027?Including solar-only and solar + storage systems ÊThe goal is not realistically achievable by 2027ÊThe projected net cost to GWP ratepayers is $23-$45 million from 2024 to 2027. This estimate accounts for bill savings, utility incentives, and avoided costs.ÊElectric rates could increase in various adoption scenarios, in addition to other sources of anticipated rate growth•By 2025: 3%-6%•By 2027 (interpolated): 4%-8%•By 2030: 6%-11%ÊPrerequisites needed:1.Robust community outreach and support2.Improved permitting processes3.Available solutions to address split incentives Achieving 10% Adoption by 2027
•Achieving 10% adoption by 2030 is theoretically feasible, but with a significant investment and retail rate impact on GWP ratepayers.•The adoption level results will be further limited by implementation barriers, customer adoption behavior, and other financial and non-economic barriers that customers face. As a result, utility program costs are expected to be higher to account for those factors.

Eligible Solar System Configurations
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1.Customer storage owned, financed, or leased by single-family and multi-family property owners/managers and commercial and industrial customers2.Subscribers of off-site solar and storage solutions like community solar/storage, solar/storage share, and green rate options3.To fill in the gap, options like distribution grid storage, customer storage at city-controlled sites, or GWP-installed storage hosted on customer sites could be explored All options must be carefully evaluated for cost-effectiveness against other storage solutions, particularly lower-cost utility-scale city-owned options.

Can GWP reach 10% customer storage adoption by 2027?Including solar + storage systems ÊThe goal is not theoretically feasible considering upfront costs and storage attachment rates in California.ÊThe impact of incentives on accelerating storage adoption is limited since battery storage has historically been driven by resiliency considerations rather than economic factors. ÊSubstantial upfront costs and diminished benefits, including low TOU participation and symmetric NEM rate schedules, hinder adoption. ÊOnly 7% of customer solar systems in Glendale have battery storage. Across California, only 6%- 19% of customer solar systems have storage, varying by income level. Achieving 100% attachment rates requires significant utility interventions.

Achieving 10% Adoption by 2027
•Achieving 10% customer storage adoption by 2027 is very ambitious and not theoretically feasible considering the realistic level of storage attachment rates in California.•Additional study is needed to determine a more realistic and achievable target.

Eligible Storage System Configurations
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Peak load reductions decline with increasing solar and storage adoption Solar Impact on Net Load(MW)
Hour of Day
Storage Impact on Net Load(MW)
Hour of Day

ILLUSTRATIVEILLUSTRATIVE
Incremental Solar Additions (10 GW in total)
Incremental Storage Additions (5 GW in total)
•Net peak load shifts to after sunset•Effective capacity per MW of storage declines 398 of 559

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Can GWP reach 100 MW dispatchable and peak load reduction capacity by 2027? ÊCustomer-owned solar and storage would provide reliable peak load reductions of 10 MW or less by 2027ÊIncluding other DERs such as demand response, managed electric vehicle charging, and energy efficiency could theoretically provide peak load reductions of 20-44 MW by 2027ÊEffective Capacity: achieving 100 MW of reliable peak load reduction could require 200-300 MW customer solar, 40-60 MW customer storage, and other DERsÊNameplate Capacity: theoretically feasible with significant utility investment and a later target year Achieving 100 MW additional effective capacity, considering DER’s ability to reduce GWP system peak demand, will require 200-300 MW DER nameplate capacity coming online by 2027. Additional study is needed to determine a more realistic and achievable target. 399 of 559

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Can GWP reach 100 MW dispatchable and peak load reduction capacity by 2027?ÊCustomer-owned solar and storage would provide reliable peak load reductions of 10 MW or less by 2027ÊIncluding other DERs such as demand response, managed electric vehicle charging, and energy efficiency could theoretically provide peak load reductions of 20-44 MW by 2027ÊEffective Capacity: requires approximately 200-300 MW customer solar, 40-60 MW customer battery storage, and other DERs by 2027ÊNameplate Capacity: theoretically feasible with significant utility investment, suggest considering a MW nameplate capacity goal and a later target year Achieving 100 MW Additional DER by 2027:
•Achieving 100 MW additional effective capacity, considering DER’s ability to reduce GWP system peak demand, will require 200-300 MW DER nameplate capacity coming online by 2027.•A more realistic target is achieving 100 MW additional DER nameplate capacity with a later target year.

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Key Takeaways: Cost and Benefit AnalysisParticipant Perspective•In all scenarios, solar and solar + storage provide net benefits over the system's lifetime•Net benefits are driven by high bill savings under various billing mechanisms, even under net billing•Despite lifetime savings, high upfront costs of solar and solar + storage may still pose barriers to adoption SocietalPerspective•Solar and solar + storage provide net benefits to society across all scenarios Ratepayer Perspective•All adoption scenarios have net ratepayer costs, meaning compensation provided to solar and solar + storage customers higher than the cost savings for GWP•A strategically planned program and incentive portfolio can achieve higher solar and storage adoption with lower impacts on GWP ratepayers 401 of 559

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Findings: Achieving the adoption goals by 2027 is not feasibleAchieving a goal of 10% customer solar adoption by 2027 is not feasible. The goal is theoretically feasible by 2030 with a significant increase in utility costs and effort, but real-world barriers remain.Achieving a goal of 10% customer storage adoption in the near future is not feasible. Achieving a goal of 100 MW of reliable peak load reduction with DERs is not feasible.

Industry studies suggest that achievable potential is 20%-40% of the technical potential. 402 of 559

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Findings: Adoption of customer-owned solar and storage increases GWP rates The scenarios achieving 10% solar adoption would result in a projected net cost of $23-$45 million to GWP ratepayers from 2024 to 2027. §Implement a Net Billing Tariff to reduce the cost shift.§Develop and implement non-bypassable charges and fixed customer charges to reduce the cost shift.§Evaluate the cost and feasibility of changes to GWP’s billing and metering systems needed to implement a Net Billing Tariff.

The resulting rate increase would be 6-11% by 2030, with a low- and moderate-income (LMI) customer monthly bill increase of $4-$6.

Recommendations
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Findings: Current customer-owned solar and storage adoption is predominately by single-family homeowners above the median incomeCustomer solar adoption in Glendale to date is above 10% for single-family homes and below 1% for renters and LMI customers.84% of customer solar adoption is in households above the median income. 88% of customer solar adoption is by property owners.
90% of customer solar adoption is in single-family homes. §Allow lower cost community solar and storage to count towards achieving the adoption goal.§Evaluate virtual solar programs that renters and LMI customers can subscribe to.§Evaluate the cost and feasibility of changes to GWP’s billing and metering systems needed to implement virtual solar programs.

Recommendations
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Findings: Customer-owned solar and storage provides limited reliable peak capacity reduction §Implement TOU rates that encourage customer storage adoption and dispatch for peak capacity reductions.§Study and expand demand response, electric vehicle, energy efficiency, utility dispatchable DER, and other programs for peak load reductions.§Evaluate the cost and feasibility of changes to GWP’s billing and metering systems needed to implement TOU rates and utility dispatchable DER.

The effective capacity of customer-owned solar is less than 10% of the installed capacity.

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Findings: Additional costs not included in this study will be required §Evaluate Glendale-specific program elements that will be the most effective for increasing DER adoption by renter, LMI, and DAC customers.§Evaluate the cost and feasibility of necessary changes to GWP’s billing and metering systems.§Consider the cost of additional program overhead and customer outreach.

Recommendations
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Findings: Adoption Strategies
Utility interventions are necessary (utility support + utility incentives).•Utility interventions are necessary to accelerate customer adoption.•Enhancing customer outreach, support, and simplifying the permitting process alone can boost solar adoption to reach 10% adoption by 2030 without further utility interventions but have a limited impact on promoting battery storage adoption.•Providing additional utility incentives and access for renter and LMI customers are also needed to accelerate customer adoption, along with improving utility support.

Building code-compliant solar and storage adoption from new construction contributes significantly to achieving the adoption target.•By the end of 2027, the adoption of building code-compliant customer solar and storage systems could account for 15% to 20% of the total customer adoption required to meet the 2027 target, assuming a 90% compliance rate (due to exceptions and waivers). 407 of 559

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Conduct comprehensive outreach and educational campaigns to enhance awareness and empower residents to make informed decisions with an understanding of the underlying economics Enhance outreach and educational campaigns to improve customer awareness and empower residents Additional outreach on federal and state support (IRA, SGIP , etc.) Proposed adoption programs that use mechanisms that customers intuitively understand Comprehensive outreach and knowledge campaigns from GWP to inform and educate residents: 1) Enhance awareness, 2) Understand costs and benefits, 3) Grasp the economics involved, and 4) Enable informed decision-making 408 of 559

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ÊA significant volume of permits must be processed in the near term when customers begin installing DERs; this volume has the potential to overwhelm the existing City of Glendale processes.ÊGWP needs a faster, easier, and more scalable permitting, interconnection, and approval process to reduce barriers and constraints to DER adoption.

Reduce permitting and interconnection fees and provide waivers for low-income customers.

Allow solar systems to be sized for future load growth from electric vehicles and appliances. 409 of 559

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Findings: Program OptionsThe balance between cost, affordability, and adoption impact must be carefully considered when selecting program portfolios to ensure that GWP equitably meets its adoption targets.•Continuing current NEM will have higher costs - continuation of the current NEM policy primarily benefits single-family homeowners, with a projected rate increase of 6% by 2030.A strategically planned program and incentive portfolio can achieve higher solar and storage adoption with lower impacts on GWP ratepayers.NEM Rate Design Evolution •Lower costs can be attained through the adoption of the Net Energy Billing (NEB) system with lower export compensation that better aligns with system costs (along with adders to protect customer investment payback period), which is more equitable than Glendale's current NEM program.•Customers will receive lower bill savings, which could slow adoption from single-family households. However:•Expanding program eligibility to the multi-family sector will create a new source of customer adoption•Cost shifts are reduced•Additional incentive programs can be implemented to increase the adoption rate Additional Incentive Programs•Improve customer economics: Adoption from multifamily, rental, and LMI/DAC households and customers in pollution-burdened areas can be accelerated by additional utility incentives, such as:•Upfront incentives and performance-based incentives that secure customer payback for 5-7 years•Direct install programs targeted at these customer segments•Prioritize breadth over depth: Direct install in targeted customer sectors is less cost-effective than incentive programs that have lower incentive levels but with broader customer eligibility•Strength in numbers! 410 of 559

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Strategically planned programs and incentives could boost solar and storage adoption while reducing impacts on GWP ratepayers Solar LeaseCustomers pay a monthly fee for installing solar panels on their roofs.

Community SolarCustomers subscribe to a share of a larger solar installation and pay a monthly fee to receive bill savings.

Virtual SolarCustomers in multi-unit buildings can subscribe to a shared solar installation.

On-Bill FinancingThe utility pays the upfront costs, which are then recovered on customer bills.

Green RatesCustomers pay a higher electricity rate to opt for 100% clean energy.

Provide Access for Renter and LMI CustomersProvide off-site solar, virtual solar, and financing programs to address split incentives between owners and tenants:Provide More Utility SupportEnhance customer outreach and support, and simplify the permitting process Consider Alternatives to NEMAdopting a Net Billing Tariff can reduce cost shifts to other GWP ratepayers and be more equitable than Glendale’s current NEM program Provide Additional IncentivesTo accelerate adoption among multifamily, renter, and LMI/DAC/pollution-burdened customers, consider the following:•Upfront or performance-based incentives to improve payback to 5-7 years•Offer $1.0-1.5/W incentives for both solar and storage•Broader customer eligibility with lower incentives are typically most cost effective than targeted customer groups with higher incentives •Lower export compensation to align with system avoided costs•Consider avoided cost adders to improve the customer’s payback period 411 of 559

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ÊWhile E3's analysis outlines several promising options to accelerate DER adoption, it is important to recognize the practical limitations GWP faces.ÊAchieving the ideal program outcomes will require addressing these implementation challenges and balancing what should be done with what can realistically be achieved, considering GWP’s existing infrastructure and resources.

Practical challenges in implementing recommended program options must be considered Renter and LMI CustomersVirtual Solar Option: providing virtual solar options for renter and LMI customers is essential for addressing financing and split incentive challenges, but it will require a major billing system upgrade, which will include budgeting for development costs, determining staff requirements, and setting realistic timelines for deployment.

Provide More Utility SupportEnhanced Community Outreach: Managing a more robust community outreach program will require significant internal resources, including staff and potentially new tools or partnerships to engage a broader segment of GWP customers.Permitting Improvements: Improving the permitting process will require coordination across departments, external stakeholders, and potentially new tools for the inspection process, adding complexity to timelines.

NEM CompensationCustomer Billing System Limitations: GWP’s current billing system currently cannot deploy TOU rates to all customers. Upgrading the system to handle TOU rates will take considerable time and investment, delaying full implementation.

Customer Support Programs: Expanding GWP’s capacity to provide direct customer support, such as education on DER options and financial assistance, will require substantial operational changes, including new staffing, training, and communication workflows.

NBT Adoption: Adopting a NBT requires City Council approval. This includes filing a regulatory-grade avoided cost analysis to determine export rate compensation. The filing process could be lengthy and complex, making it unlikely to be available by early 2025. 412 of 559

Section 11Appendix
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ÊNREL REPLICA dataset provides estimates of residential rooftop solar technical potential at the U.S. census tract level with emphasis on low-to-moderate income (LMI) populations•Derived from rooftop suitability modeling for 128 U.S. cities and metropolitan areas using LiDAR data from the Department of Homeland Security, representing approximately 40% of the population•A statistical model trained on areas with data coverage was used to estimate technical potential for the rest of the nationÊIncludes estimates of the number of households, number of suitable buildings, number and area of developable planes (m2), total capacity potential (MW), and total annual generation potential (MWh) for each of 20 demographic combinations:•Area Median Income (0-30% AMI, 30-50% AMI, 50-80% AMI, 80-120% AMI, >120% AMI)•Housing Type (multi-family vs. single-family)•Tenure (renter vs. owner)ÊDemographic data from 2011-2015 American Community Survey (ACS) 5-Year Estimates combined with LiDAR data to estimate solar technical potential at tract level by income, building type, and tenure NREL Rooftop Energy Potential of Low-Income Communities in America (REPLICA) LiDAR Data Coverage
Residential Rooftop Solar Technical Potential (GWh)
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SB535 Disadvantaged Communities (DACs)Share of combined multi-family, renter, and LMI customers Rooftop Solar Technical Potential (MW per km2 Census Tract Area)% Combined MF , Renter, and LMI Customers(by Census Tract) NREL REPLICA Residential Rooftop Solar Technical Potential in Glendale 415 of 559

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1357911131517192123
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Load flexibility can come in many forms
1357911131517192123
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V1G V2G Solar PVBattery Storage
Space CoolingSpace HeatingWater Heating Pool Pump
Greatly reduces peak-coincident chargingShaves peak
Exports to the grid
Optimal shift of solar net load(on left)
Peak cooling load shifted to low-cost solar hoursSmooths out heating loadSpreads water heating across lower-cost hours Aligns pump load with solar generation Original LoadLoad after FlexibilityGreatly reduces peak-coincident charging Serves building/grid load in high-cost hours
•V1G: One-directional smart charging that allows vehicles to charge from the grid at different times and speeds.•V2G: Bi-directional capability that enables vehicles to both charge from and discharge to the grid. 416 of 559

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DERs may provide many benefits, but not all provide measurable benefits to ratepayers ÊData accessÊEquipment ratings and performanceÊEnvironmental justice benefitsÊLocal workforce benefits ÊEconomic developmentÊTechnology developmentÊImproved public awareness ÊProcurement cost reductionÊTransmissions capacity savingsÊDistribution capacity savingsÊEmissions savingsÊOperations and maintenance savings ÊFuel cost savingsÊReserve capacity costs reductionÊLine loss reductionÊReduced methane leakageÊEnvironmental justice benefitsÊVoltage regulation/optimizationÊFinancial risk reductionÊReliabilityÊResilience ÊEmissions savingsÊLand use impactsÊReduced water consumptionÊBringing in federal incentive dollarsÊReduced criteria pollutants Qualitative Benefits
Monetized Benefits(Ratepayer POV)= Avoided Costs
Quantifiable Benefits
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City of Glendale

DISCLOSURE - CAMPAIGN FINANCE ORDINANCE
The City Council adopted Ordinance No. 5744, “Campaign Finance Ordinance,” which became effective on September 9, 2011, and amended it with Ordinance No. 5768, which became effective on March 15, 2012 (“the Ordinance”). The Ordinance prohibits: (1) A contractor* (including a subcontractor**)― who has a contract with the City of Glendale (“City”), Glendale Redevelopment Agency (“GRA”), or the Housing Authority of the City of Glendale (“HA”) and that contract is subject to approval by the City Council, GRA, or HA― from making a contribution to a City Council member, GRA member, HA member, City Clerk, or City Treasurer; and (2) Council members, GRA members, and HA members from voting on matters concerning a contract with a person who has provided a campaign contribution.

The Ordinance applies to a contractor whose contract requires the City Council’s, GRA’s, or HA’s approval. A contract with the City, GRA, or HA is known as a “City Contract.” The Ordinance also applies to a subcontractor who has a subcontract through a City Contract. The Ordinance excludes a competitively bid contract awarded to the lowest responsible bidder.

To assist members of the City Council, GRA, and HA before they vote on a matter regarding a City Contract, the Ordinance requires City staff to prepare this report which discloses certain information about: the contractor receiving the City Contract, and the subcontractor(s) working under the City Contract.

A contractor must provide the information listed below when: A subcontractor must provide the information listed below when:
• The City Contract has a total anticipated or actual value of $50,000 or more; or • The subcontract through a City Contract has a total anticipated or actual value of $25,000 or more; or
• A combination or series of City Contracts have a value of $50,000 or more. • A combination or series of subcontracts, for the same or different projects, have an aggregate value of $25,000 or more.

Information that must be disclosed: ● Name of the person, entity, or organization (i.e., the Contractor or Subcontractor) ● Name of the Chief Executive Officer/President
● Chief Operating Officer
● Chief Financial Officer
● Chairperson
● All members of the Board of Directors
● All persons who own more than 10% of the person, entity, or organization ● Name of any campaign committee owned or controlled by the person, entity, or organization Please complete the following disclosure form:

Contractor(s)*:

Name Address
Energy and Environmental Economics, Inc. 2401 E KATELLA AVE STE 300 ANAHEIM, CA 92806-5909 Full Name
Michael A. Bieber
Title Business Address
2401 E Katella Ave, Suite 300
City
Anaheim
Anaheim
State
CA
Zip
92806
92806
Chairman of the Board
Founding Partner
President, CEO
Chief Financial Officer, Treasurer 2401 E Katella Ave, Suite 300 Secretary
Ren Orans
Amber Mahone
2401 E Katella Ave, Suite 300 CA
CA
CA
CA
2401 E Katella Ave, Suite 300 Anaheim
Anaheim
Anaheim
Anaheim
92806
92806
92806
Creighton K. Early
Kate Nguyen
Cathaleen D. Steele
2401 E Katella Ave, Suite 300
2401 E Katella Ave, Suite 300Assistant Secretary CA 92806 * “Contractor” is the person, entity, or organization that is the party, or prospective party, to the contract with the City, GRA, or HA or any member of that person’s, entity’s, or organization’s Board of Directors, its Chairperson, Chief Executive Officer, Chief Financial Officer, Chief Operating Officer, any person with an ownership interest of more than ten percent (10%) in that person, entity, or organization, and any campaign committee that is owned or controlled by that person, entity, or organization. Above please disclose these persons’ name and business address. 419 of 559

City of Glendale

DISCLOSURE - CAMPAIGN FINANCE ORDINANCE
Please complete the following disclosure form:

Contractor(s)*:

Name Address
Energy and Environmental Economics, Inc. 2401 E KATELLA AVE STE 300 ANAHEIM, CA 92806-5909 Full Name Title Business Address City State
CA
CA
CA
CA
CA
CA
CA
CA
Zip
Arne Olson
Snuller Price
Senior Partner/Sr. Vice-President 2401 E Katella Ave, Suite 300 Senior Partner/Sr. Vice-President 2401 E Katella Ave, Suite 300 Senior Partner/Sr. Vice-President 2401 E Katella Ave, Suite 300 Senior Partner/Sr. Vice-President 2401 E Katella Ave, Suite 300 Partner/Vice-President
Partner/Vice-President
Partner/Vice-President
Partner/Vice-President
Anaheim
Anaheim
Anaheim
Anaheim
Anaheim
Anaheim
Anaheim
Anaheim
92806
92806
92806
92806
92806
92806
92806
92806
Brian Horii
Kush Patel
Lakshmi Alagappan
Nick Schlag
Victoria Clark
2401 E Katella Ave, Suite 300
2401 E Katella Ave, Suite 300
2401 E Katella Ave, Suite 300
2401 E Katella Ave, Suite 300Eric Cutter
Dan Aas Partner/Vice-President 2401 E Katella Ave, Suite 300 Anaheim CA 92806 * “Contractor” is the person, entity, or organization that is the party, or prospective party, to the contract with the City, GRA, or HA or any member of that person’s, entity’s, or organization’s Board of Directors, its Chairperson, Chief Executive Officer, Chief Financial Officer, Chief Operating Officer, any person with an ownership interest of more than ten percent (10%) in that person, entity, or organization, and any campaign committee that is owned or controlled by that person, entity, or organization. Above please disclose these persons’ name and business address. 420 of 559

Subcontractor(s)**:

Name Address
Dakota Communications 707 Wilshire Blvd. Ste 3675 Los Angeles, CA 90017 Full Name Title Business Address City State Zip
Chairperson
Chief Executive Officer / President
Chief Operating Officer
Chief Financial Officer
Board of Directors
Kerman Maddox, Rick Taylor More than 10% interest owner 707 Wilshire Blvd. Ste 3675 Los Angeles CA 90017 ** “Subcontractor” is the person, entity, or organization that has entered into a contract for the performance of all or a portion of the work undertaken under an agreement with an architect, design professional, engineer, or general or prime contract, usually by a general or prime contractor. Subcontractor includes any member of that person’s, entity’s, or organization’s Board of Directors, its Chairperson, Chief Executive Officer, Chief Financial Officer, Chief Operating Officer, any person with an ownership interest of more than ten percent (10%) in that person, entity, or organization, and any campaign committee that is owned or controlled by that person, entity, or organization. Above please disclose these persons’ name and business address.

Campaign Committee owned or controlled by: N/A
Title Business Address City State Zip

CERTIFICATION
On behalf of the above-named Contractor Subcontractor:
• I acknowledge that I have a continuing obligation to update this disclosure form if I substitute― or if I select additional― architects, design professionals, contractors, or subcontractors within ten (10) days of the selection or change; and • I hereby certify that:

I have identified all persons for which the Ordinance requires disclosure; The information in this disclosure form (and any attachment to this form) is true, accurate, correct, and complete; and I have been legally authorized to submit this disclosure form. 3In total, this disclosure form (including attachments) is pages.

November 11 , 2024 AnaheimExecuted on: , at: , California.

Kate Nguyen
Print Full Name:

Signature:
240 300, Anaheim, CA 92806Address:
714.940.6300 [email protected] Number: E-mail Address:

Rev. 6/7/12 J:\FILES\DOCFILES\ORD\CAMPAIGN CONTRIBUTION\DISCLOSURE FORM – CONTRACTOR – 6-7-12.doc 421 of 559

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CITY OF GLENDALE, CALIFORNIA

REPORT TO THE CITY COUNCIL

AGENDA ITEM
Report: Appointment of City of Glendale Member to the Board of Directors for the Metropolitan Water District (MWD) of Southern California

1. Motion appointing an individual to serve on the Board of Directors for the Metropolitan Water District of Southern California

COUNCIL ACTION
Item Type: Action Item
Approved for November 19, 2024 calendar

EXECUTIVE SUMMARY
The City of Glendale needs to appoint a representative to the Metropolitan Water District (MWD) of Southern California Board of Directors as Councilmember Kassakhian’s term will expire on December 31, 2024. The MWD provides water to 19 million people in Southern California and is governed by a 38-member board. The City Council can appoint a member for an indefinite term, a four-year term, or any other term they deem appropriate.
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RECOMMENDATION
That Council appoint a representative to serve as a Board Member on the Metropolitan Water District (MWD) of Southern California.

ANALYSIS
The City of Glendale is actively engaged with various public agencies, joint powers authorities, and committees, with City Council members representing the city on many of these boards. One such agency is the Metropolitan Water District (MWD) of Southern California.

MWD is a regional wholesaler that delivers water to 26-member public agencies which in turn provides water to 19 million people in Los Angeles, Orange, Riverside, San Bernadino, San Diego, and Ventura counties. MWD is governed by a 38-member Board of Directors who represent their respective member agencies, ensuring each member agency is part of the governance of MWD. The MWD Board is responsible for establishing and administering Metropolitan’s policies and upholding the articles in the MWD Act.

MWD’s Board of Directors typically meet on the second Tuesday of each month, with various committee meetings occurring on other days. There are no stipends; however, members are reimbursed for travel and mileage to meetings at the standard rate permitted at the time by the Internal Revenue Service (The Metropolitan Water District Administrative Code, Section 6326: Authorized Expenses).

On May 5, 2020, Councilmember Kassakhian was appointed by City Council to serve as the City of Glendale’s representative on the MWD Board of Directors. This 4-year term is set to expire on December 31, 2024.

Under MWD Act, City Council has the discretion to appoint a Director to the MWD Board for either an indefinite term, a four-year term which will expire on December 31 of even- numbered years, or for any other term which the Council deems appropriate (Sections 51 and 54 of the Metropolitan Water District Act).

STAKEHOLDERS/OUTREACH
NA

FISCAL IMPACT
There is no fiscal impact associated with this report.

ENVIRONMENTAL REVIEW (CEQA/NEPA)
NA

CAMPAIGN DISCLOSURE
This item is exempt from campaign disclosure requirements.

ALTERNATIVES TO STAFF RECOMMENDATION
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1) Council may consider any other alternative not proposed by staff.

ADMINISTRATIVE ACTION
Submitted by:

Elena Bolbolian, Chief Innovation Officer
Prepared by:

Gregory Kajszo, Innovation Project Manager
Approved by:

Roubik R. Golanian, P.E., City Manager

EXHIBITS/ATTACHMENTS
None
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MOTION
Moved by Council Member ____________________________, seconded by Council Member ___________________________, that the Council of the City of Glendale hereby selects and appoints _____________________ to serve as Glendale’s representative on the Metropolitan Water District (MWD) for a term of _____________.

Vote as follows:

Ayes:

Noes:

Absent:

Abstain:
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CITY OF GLENDALE, CALIFORNIA

REPORT TO THE CITY COUNCIL

AGENDA ITEM
Report: Public Hearing Re: Ordinances Amending Title 30 of the Glendale Municipal Code, 1995, (Case No. PZC-0010-2024) and the Downtown Specific Plan (Case No.

PGPA-003908-2024) Relating Generally to Standards for Accessory Dwelling Units (ADUs) and Junior Accessory Dwelling Units (JADUs).

1. Introduction of Ordinance Amending Title 30 Relating Generally to Standards for ADUs and JADUs.

2. Introduction of Ordinance Amending the Downtown Specific Plan Relating Generally to Standards for ADUs and JADUs.

COUNCIL ACTION
Item Type: Public Hearing
Approved for November 19, 2024 calendar

EXECUTIVE SUMMARY
Zoning standards for accessory dwelling units (“ADUs”) and junior accessory dwelling units (“JADUs”) were first established in 2017 and have since been amended several times to bring them into compliance with constantly evolving State law, which requires cities to ministerially approve ADUs and JADUs subject to very limited standards.

Following a comprehensive review of the City’s ADU/JADU standards, the California Department of Housing and Community Development (“HCD”) made findings that several standards are not in compliance with State law. Staff disagrees that such standards are out of compliance, but in some cases amendments to the ADU/JADU zoning standards are recommended, and in other cases staff recommends that the Council adopt findings regarding the City’s compliance with State law despite HCD’s findings. This report discusses such proposed amendments to Title 30 of the Glendale Municipal Code (“GMC”), 1995, and the Downtown Specific Plan (“DSP”), specifically as 426 of 559

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it relates to requirements for ADUs and JADUs, as directed by City Council on August 20, 2024. Staff has summarized the areas identified by HCD and provided options for amendments to Title 30 (also referred to as the “Zoning Code”) and DSP based on City Council direction. Additional amendments to the ADU standards are proposed that reflect SB 1211, recent legislation that was signed into law by the Governor on September 19, 2024, and effective January 1, 2025, that expands the number of ADUs permitted on multi-family properties. The proposed amendments also include miscellaneous code clean-ups related to minor grammar and formatting, which do not change the substance or meaning of the text in any way. These Zoning Code amendments were reviewed by the Planning Commission on October 16, 2024 with recommendations to the City Council related to where JADUs are permitted in the city, unit mixture (number of ADUs allowed), objective design standards, accessory living quarters, and ADUs above a detached garage.

RECOMMENDATION
That the City Council review, introduce and subsequently adopt the ordinances amending Title 30 of the Glendale Municipal Code, 1995, and the Downtown Specific Plan related generally to standards for ADUs and JADUs, following a public hearing.

ANALYSIS
The City of Glendale first established zoning standards for ADUs in 2017 as a result of State legislation (AB 2299 and SB 1069) that required local agencies to ministerially approve ADUs. Since then, and in response to changing legislation from the State, the City has adopted a series of ordinances regarding zoning requirements for ADUs and JADUs on residential properties. The most recent update to the ordinance (Ordinance No. 5997) was adopted by City Council on November 15, 2022, and is codified in GMC Section 30.34.080 (“ADU/JADU Ordinance”).

In a letter dated December 7, 2023, after reviewing the City’s ADU/JADU Ordinance, HCD identified 16 general areas they contend conflict with State law. The City responded to HCD in a letter dated January 31, 2024, and addressed each of the 16 areas, analyzing reasons its ADU/JADU Ordinance complies with State law in all 16 areas, but committing nevertheless, to bring forth certain clarifying and other amendments to City Council for consideration. Since then, a series of written communications were exchanged with HCD regarding the ADU/JADU Ordinance, including a Notice of Violation issued by HCD on June 19, 2024 that requires the City to either amend its ADU/JADU Ordinance to satisfy HCD’s findings of non-compliance, or 427 of 559

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adopt its own findings to explain reasons its Ordinance complies with State law.1 The City responded to the June letter by reiterating its position that its ADU/JADU Ordinance complies with State law, but ultimately, the City committed to a timeline for potential adoption of various amendments (or findings, as the case may be) to the Ordinance by early November of 2024. On August 20, 2024, the City Council adopted a series of motions to initiate amendments to the ADU/JADU Ordinance based on the topics associated with the 16 areas HCD initially identified in its December 7, 2023, letter, as described below.

1. Dwelling Unit Size

2. Where JADUs are Permitted*

3. ADUs in Proposed Multi-Family
Development

4. Size Limits on Attached ADUs

5. JADUs and Development Standards

6. Accessory Living Quarters*

7. Street-Front and Street-Side Setback

8. JADUs and Short-Term Rentals

9. JADUs and Separate Sales

10. Unit Mix – Number of ADUs Allowed

11. Architectural Compatibility

12. ADUs Above a Detached Garage*

13. ADUs in Proposed Multi-Family
Development (Similar to #3)

14. Parking

15. Covenant and Agreement
Requirements

16. JADUs and Owner Occupancy
1 Government Code Section 66326(b)(2) provides that if HCD finds a city’s ordinance does not comply with State law, a city must either amend its ordinance to make changes HCD claims are necessary to achieve compliance, or “[a]dopt the ordinance without changes. The [city must] include findings in its resolution adopting the ordinance that explain the reasons the local agency believes that the ordinance complies with [State law] despite the findings of [HCD].” 428 of 559

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For a majority of the above-referenced areas, staff agrees that clarifying amendments to the City’s Zoning Code and DSP are prudent, and has included recommended amendments within the draft ordinances to address the areas. These 16 topics are also discussed in a matrix included as Exhibit 7 to this report. Also, some of these topics are related to what is commonly referred to as a “mandatory ADU”, which is an ADU that must be allowed, regardless of compliance with other zoning development standards (e.g., FAR, lot coverage, landscaping, etc.) as long as it is limited to 800 square-feet (SF) in size for single-family properties and 1,000 SF for multi-family properties, located at least four feet away from an interior setback and complies with the specified height requirements that range from 16 to 25 feet depending on location on-site and proximity to major transit. Gov’t Code Section 66321(b)(3); GMC Section 30.34.080(E)(2). If the City disagrees with HCD’s findings on any area, and determines no amendments are necessary, Government Code Section 66326 requires the City to adopt findings explaining why its ordinance complies with State law, and to re-adopt the language of the ordinance. A resolution is included that contains findings required by Government Code Section 66326 for those areas the City Council votes to re-adopt the City’s existing ordinance provisions.

The following paragraphs summarize the recently approved SB 1211 and how it impacts Glendale’s ADU/JADU Ordinance and each of the 16 HCD-identified areas and staff’s recommended course of action (whether to amend or adopt findings of compliance). For those items noted with an asterisk (*), staff is bringing forth alternatives for consideration, based on Council direction during the August 20, 2024 hearing. These items were discussed at length, and there was a lack of consensus of at least four Councilmembers. The alternatives in the draft ordinances are illustrated using bold italic underline and bold italic underline strikeout, as applicable. These alternatives are presented in the draft ordinances and also detailed below with each topic. Staff prepared alternatives in the draft ordinances for Planning Commission’s consideration and recommendation in this manner, and has kept the same format here.

SB 1211
On September 19, 2024, Governor Newsom signed into law SB 1211 which amends existing legislation related to ADUs, as detailed below, and goes into effect on January 1, 2025. This law was approved after the amendments to the ADU/JADU Ordinance were initiated by the Council on August 20, 2024, and staff is incorporating these amendments into the draft ordinance in order to be in compliance with the new laws effective at the beginning of next year.
•Livable Space - A new definition for “livable space” is added for the purposes of an ADU and includes the space in a dwelling intended for human habitation, 429 of 559

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including living, sleeping, eating, cooking or sanitation. An amendment to GMC Section 30.34.080(C) is proposed to add this definition. •Replacement Parking – Current law prohibits local agencies from requiring the replacement of parking when a garage, carport, or covered parking structure is demolished in conjunction with the development of an ADU. SB 1211 further expands the applicable parking exception to also include the removal of an uncovered parking space for the development of an ADU. An amendment to GMC Section 30.34.080(H)(5) is proposed to include this new exception. •Detached ADUs on Multi-Family Properties – Current law allows no more than two (2) detached ADUs on a property developed with a multi-family dwelling. SB 1211 increases the number of ADUs allowed on an existing property developed with a multi-family dwelling from no more than two (2) detached ADUs to no more than eight (8) detached ADUs, provided that the number of ADUs does not exceed the number of existing dwelling units on the lot. As an example, an existing multi-family property developed with five (5) units is entitled to no more than five (5) detached ADUs. The law also stipulates that this would only apply for a property with existing multi-family dwelling units –properties proposed to be developed with multi-family dwelling units would still be limited to the maximum of two (2) detached ADUs. An amendment to GMC Section 30.34.080(F)(2)(b) is proposed to include these changes.
•Mandatory ADUs and Objective Design Standards – SB 1211 also adds language clarifying that a local agency shall not impose any objective development or design standards for mandatory ADUs, aside from the size, the four-foot interior setback requirement and the specified height requirements that range from 16 to 25 feet depending on location on-site and proximity to major transit, as specified in Government Code Section 66323 (a). The proposed amendments to GMC Section 30.34.080 include the creation of objective design standards, as directed by the Council at the August 20, 2024 hearing, and clarifying language has been included in the ADU/JADU Ordinance that exempts mandatory ADUs from the requirements. Note that this recent amendment to State law renders any objective design standards that are meant to be applicable to ADUs generally inapplicable to mandatory ADUs.

Sixteen Areas, HCD Findings
Dwelling Unit Size
HCD references GMC Section 30.11.050 and claims that Glendale’s minimum dwelling unit sizes for ADUs and JADUs are more restrictive than the State’s required minimums. 430 of 559

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This is a misunderstanding; the standards for minimum dwelling unit sizes in GMC Section 30.11.050 are specifically for standard dwelling units in multi-family zones and under no circumstances apply to ADUs or JADUs, which are defined separately with separate standards. In response to this claim, staff is proposing amendments to the referenced section to clarify that the dwelling unit sizes in GMC Section 30.11.050 do not include ADUs or JADUs, which are defined and governed separately in GMC Section 30.34.080. An additional amendment to the definition of dwelling unit in GMC Section 30.70.050 is proposed to add a clarifying statement the ADUs and JADUs are defined separately. Planning Commission concurred with Council’s August 20 direction to adopt this amendment.

Where JADUs are Permitted*
Government Code Section 66333 restricts JADUs to lots in single-family residential zones with either an existing or proposed single-family dwelling unit. HCD claims that the City’s ADU/JADU Ordinance violates State law because JADUs are also permitted in the multi-family, commercial, mixed-use, special purpose, and transit-oriented development zones. The definition of a JADU and the standards specified in GMC Section 30.34.080 are clear that JADUs are restricted to single-family properties, meaning there is only one dwelling unit on the site, regardless of zone. This was done intentionally in order to be fair and equitable to the many single-family use properties located throughout different zones of the City. The City acknowledges that State Law restricts JADUs to single-family residential zones, but in adopting regulations, the City did not interpret this provision as a prohibition on allowing JADUs on single-family use properties in other zones. Implementing this change will require amendments to the land use charts in the zoning code and DSP to omit references to JADUs. Moving forward, those properties that are developed with a single-family use outside of a single- family zone would no longer be eligible to construct a JADU and would be restricted to one ADU.

Council’s Initial Direction and Planning Commission Review Government Code Section 66333 allows a local agency to allow the creation of JADUs in single-family residential zones, but nowhere else. Accordingly, staff is recommending to amend the land use charts in Title 30 and the DSP to address HCD’s claim, and no longer allow JADUs on properties developed with a single-family residence outside of a single-family zone. During the August 20, 2024 hearing, Councilmembers Gharpetian and Najarian were in favor of amending Title 30 and the DSP to address HCD’s claim.

Councilmembers Brotman, Kassakhian and Asatryan were in favor of not amending the ADU/JADU Ordinance and directed staff to draft the necessary findings in accordance with Government Code Section 66326 to keep this provision as-is. (See City Council Motions, Exhibit 1).
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Based on Council direction, staff is providing alternatives in the draft ordinances with the changes to the land use tables in Title 30 and the DSP illustrated using bold italic underline and bold italic underline strikeout. The amendments to the land use table in Chapter 30.11 (Residential Districts) create a new category for JADUs on a lot with a single-family residence and permits them in the three single-family zones (ROS, R1R, and R1) only. The land use tables for the other chapters of Title 30 and the DSP omit the reference to JADUs in their entirety. Additionally, an amendment will be necessary to the land use table in the DSP to omit the reference to JADUs on multi-family properties. This is an error that will need to be corrected, regardless of council’s decision to either change the code or make the required findings as JADUs are not permitted on multi-family properties under any circumstances.

All five Planning Commissioners unanimously recommended that the City Council find that this portion of the current ordinance does not violate Government Code Section 66333, and that the Council adopt the required findings outlining the reasons why the City’s allowance of JADUs in zones other than single family residential zones complies with State law. (See Planning Commission Motions, Exhibit 2).

ADUs in Proposed Multi-Family Development
This topic appears twice in HCD’s December 2023 letter and pertains to GMC Sections

30.34.080(D)(1) and 30.34.080(F)(4), which appears to prohibit (or rather, exclude the allowance of) ADUs in proposed multi-family developments, where State law allows ADUs in proposed multi-family developments. This was an oversight and the City never intended to exclude proposed multi-family developments from constructing ADUs. The City has always allowed and will continue to allow a proposed multi-family development to construct ADUs as part of the development in accordance with applicable standards.

Staff is proposing amendments to both referenced code sections to clarify that ADUs are allowed in proposed multi-family development, which will be consistent with current practice. Planning Commission concurred with Council’s August 20 direction to adopt this amendment.

Size Limits on Attached ADUs
The development standards in GMC Section 30.34.080(D)(7) include restrictions on the size of ADUs that are proposed to be attached to existing single-family residences, where the attached ADU cannot exceed 50% of the existing square-footage of the house. HCD claims that this provision violates State law because it would preclude an owner from developing a “mandatory ADU” which is restricted to a maximum size of 800 SF. Currently, the City abides by the requirement of State Law to allow an exception to the development standards when they would preclude the construction of a “mandatory ADU”. Staff is proposing amendments to the referenced code section to clarify that the 432 of 559

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50% restriction does not apply to the “mandatory ADUs”, which will be consistent with our current practice. Planning Commission concurred with Council’s August 20 direction to adopt this amendment.

JADUs and Development Standards
HCD cites GMC Section 30.34.080(D)(3) and claims that the City is in violation of State Law because the proper exception for JADUs is not specified in the ordinance as it relates to JADUs and the underlying zoning development standards. However, this is incorrect, because the GMC states that ADUs and JADUs are subject to the underlying zoning development standards applicable to the primary dwelling, except as set forth in the section. Staff is proposing amendments to the referenced code section to include a clarifying statement that specifically cites the code section for the mandatory ADUs and JADUs not subject to underlying zoning development standards. Planning Commission concurred with Council’s August 20 direction to adopt this amendment.

Accessory Living Quarters*
GMC Section 30.34.080(D)(9) establishes restrictions on single-family properties and allows either an ADU or accessory living quarters, but not both. An accessory living quarter can include any building with an “R” Occupancy per the California Building Code. Common examples include a guest house, pool house, recreation room, workshop, and rumpus room. In their findings letter, HCD cites Government Code Section 66314(d)(3), which provides a choice of the type of ADU created and includes attached or located within the primary dwelling (including attached garages, storage areas or similar uses), or an accessory structure. HCD alleges that because there is no language in State Law requiring existing accessory living quarters to be converted to an ADU, that the City’s restriction is in violation. Staff contends that since there is no language in State law specifically prohibiting a local agency from requiring a property with existing accessory living quarters from either converting it or demolishing it to build an ADU, that there is no violation of State law. Additionally, the intent of this restriction was to minimize a proliferation of detached accessory buildings on lots which further reduces landscaping and open space, and contributes to additional lot coverage and FAR, and to encourage applicants to convert accessory living quarters to ADUs which contributes to independent living facilities to support renters.

Council’s Initial Direction and Planning Commission Review During the August 20, 2024 hearing, Councilmembers Brotman and Asatryan were in favor of amending Title 30 and the DSP to address HCD’s claim regarding accessory living quarters. Councilmembers Gharpetian, Kassakhian and Najarian were in favor of not amending the ADU/JADU Ordinance and directed staff to draft the necessary findings in accordance with Government Code Section 66326 to continue to prohibit 433 of 559

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both an ADU and accessory living quarters on a property (Exhibit 1). Based on Council direction, staff is providing an alternative in the draft ordinance to amend the referenced section, with the changes illustrated using bold italic underline strikeout. If this change is implemented, accessory living quarters would continue to be regulated through the zoning development standards including setbacks, height, floor area, lot coverage, landscaping and design review. Moving forward, property owners would be able to maintain their accessory living quarters and build an ADU. During the October 16, 2024 hearing, there was a unanimous recommendation from the Planning Commissioners that the City Council should amend the current ordinance and omit the requirement that a lot with one residential unit may have either an ADU or an accessory living quarter, but not both. (See Planning Commission Motions, Exhibit 2).

Street-Front and Street-Side Setback
Regardless of the city’s street-front and street-side setback requirements, if construction of a “mandatory ADU” would be prohibited by such requirements, the City must allow such “mandatory ADU” in the street-front and street-side setback areas so long as the 4’-0” interior setbacks are provided. The City’s current language in GMC Section

30.34.080(D)(10) already allows this for single-family properties in accordance with State Law. Staff oversight in drafting the ordinance originally excluded the multi-family ADUs in the language, however, our practice is to allow them in accordance with State Law. Staff is proposing amendments to the referenced section to include clarifying language that includes multi-family properties. Planning Commission concurred with Council’s August 20 direction to adopt this amendment.

JADUs and Short-Term Rentals
The City has established a minimum rental term of over 30 days for ADUs and JADUs in the Zoning Code. GMC Section 30.34.080(D)(11) (“Any rental of an accessory dwelling unit and/or junior accessory dwelling unit created pursuant to this section shall be for a term longer than 30 days.”) In other words, ADUs and JADUs cannot be used as home-sharing short-term rentals. HCD claims that the City is in violation of State law as it relates to JADUs because there are no restrictions on the rental terms established in State law for JADUs. Government Code Section 66315 establishes a minimum rental term of over 30 days for ADUs and is silent on JADUs. Staff disagrees that just because State law does not specify a minimum rental term for JADUs, that does not mean the City cannot impose one. Having said that, the Council did not direct staff to prepare the required findings to contend HCD’s claim, and staff is proposing an amendment to the referenced section to remove the restriction on JADU rental terms, which would allow 434 of 559

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JADU owners to rent their property on a short-term basis (subject to JADU owner- occupancy requirements and the City’s home-sharing regulations). Planning Commission concurred with Council’s August 20 direction to adopt this amendment.

JADUs and Separate Sales
Starting January 1, 2024, cities have the option to allow the separate sale of ADUs from the primary dwelling, but the separate sale of JADUs is prohibited. HCD claims that the City should clarify that prohibition for JADUs. Staff disagrees that a clarification in the City’s ADU/JADU Ordinance is necessary because the current Ordinance language already references the applicable sections of the Government Code. However, since this amendment would not be substantive, staff is proposing an amendment to GMC Section 30.34.080(D)(11) to clarify that a JADU may not be sold separately under any circumstances. Planning Commission concurred with Council’s August 20 direction to adopt this amendment.

Unit Mix – Number of ADUs Allowed
HCD claims that the provisions of Government Code Section 66323(a)(1) thru (4) require the City to allow a maximum of three units to be permitted on single-family properties consisting of one converted ADU, one detached new construction ADU, and one JADU. On multi-family properties, HCD claims that State law allow owners to combine the right to build two detached ADUs and multiple ADUs by converting existing non-livable space. The City does not agree that the intent of the referenced sections of State Law is to allow up to three accessory units on single-family properties, and multiple accessory units on multi-family properties by combining new construction and conversions.

The City Attorney’s Office researched the legislative history of AB 68 and AB 881 (the bills that amended State ADU law to allow these combinations in 2019), and both contain reports evidencing that the legislature intended to allow a maximum of one ADU and one JADU in single-family developments. For example, with respect to AB 68, the April 3, 2019 report titled "Assembly Committee on Housing and Community Development", on page 4 under the heading "Relaxing ADU Standards", states: "[t]his bill makes major changes to the ADU statute to facilitate the development of more ADUs ... , including the following: Increases the number of ADUs allowed to be constructed per lot by potentially allowing two ADUs on lots with single-family homes, and multiple ADUs on lots with multi-family dwellings." Similar language is contained in the September 9, 2019 report titled "Concurrence in Senate Amendments", at page 2 ("This bill ... [i]ncreases the number of ADUs allowed to be constructed per lot by potentially allowing two ADUs on lots with single-family homes, and multiple ADUs on lots with multi-family dwellings.") Moreover, with respect to AB 881, the Senate Floor 435 of 559

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Analysis dated September 1, 2019 contains a table on page 5 that delineates that each lot may only have one JADU and one ADU.

HCD argues that the word "any" contained in Government Code Section 66323(a)(1-2) means that a property owner could construct any and all (a phrase that is missing from State law) of what follows. This is a strained and illogical reading of this section that contradicts the overall ADU/JADU statutory scheme. Section 66323's language requires a local agency to ministerially approve an application "to create any of the following" and then delineates what is clearly two different and distinct alternate scenarios: 1) a "converted" ADU and a JADU meeting certain specifications; or 2) a detached new construction ADU and a JADU. The legislature was clear that each type of ADU (converted or new construction) could also combine with a JADU (and only one JADU with each type of ADU). Under HCDs reading of the statute, requiring the allowance of any and all of the listed types of ADUs/JADUs on one lot, an applicant could create each of the two kinds of ADUs and a JADU for each ADU (resulting in 2 ADUs and 2 JADUs). However, a lot cannot have more than one JADU pursuant to Government Code Section 66333. Accordingly, HCDs construction of the statutory language is not in harmony with Section 66333, and thus violates the rules of statutory construction. See Skidgel v. California Unemployment Ins. Appeals Bd., 12 Cal. 5th 1, 14 (20 21) (holding court must "construe the words in question in context, keeping in mind the statutes' nature and obvious purposes. . .. [and] harmonize the various parts of the enactments by considering them in the context of the statutory [framework] as a whole"). The same statutory construction should thus apply to section 66323(a)(3-4), in that an applicant must choose either two detached ADUs or conversion of non-livable existing space up to 25% of the existing units. Accordingly, the City’s position is that this section of its ADU/JADU Ordinance is in compliance with State law. During the August 20, 2024 hearing, Council directed staff to keep the language in Title 30 as-is and draft the necessary findings in accordance with Government Code Section 66326 explaining why the City is in compliance with State law (See City Council Motions, Exhibit 1). Planning Commission concurred with the Council’s direction and unanimously recommended that the City Council re-adopt the ordinance and adopt findings. (See Planning Commission Motions, Exhibit 2).

Architectural Compatibility
As it relates to design, State law allows local agencies to establish objective standards for ADUs. The current zoning standards in GMC 30.34.080 establish an “architectural compatibility” requirement for ADUs which means the proposal must use matching or complementary building materials unless compliance would preclude the development of a “mandatory ADU”. HCD claims that the “architectural compatibility” requirement is subjective and therefore the city is in violation of State law. Accordingly, staff is proposing amendments to the ADU/JADU Ordinance to include objective design 436 of 559

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standards, similar to those that were created for SB 9 units, but focusing on façades directly facing the public realm and second-story additions. The proposed objective design standards will address massing and overall design and detailing and will include specific requirements for roof form and pitch, breaks in building volume, exterior wall cladding, roof cladding, entryways, windows, doors, balconies, stairs, landings, equipment location and lighting locations.

As noted above, SB 1211, which was signed into law by the Governor after the Council initiated amendments to the Code, goes into effect on January 1, 2025. One of the changes to the existing legislation governing ADUs and JADUs involves the applicability of objective design standards. Under this new law, the City is prohibited from imposing objective development or design standards on mandatory ADUs, which are limited to 800 SF in size for single-family properties and 1,000 SF for multi-family properties, located at least four feet away from an interior setback and complies with specified height requirements which range from 16 to 25 feet. Mandatory ADUs can also include a second-story attached to a primary residence and ADUs above a detached garage, so long as they meet the size, setback, and height criteria noted. Accordingly, any objective design standards that are adopted would only be applicable to non-mandatory ADUs. Despite the fact that objective design standards will not be applicable to mandatory ADUs, the Planning Commission concurred with Council’s August 20 direction to adopt this amendment to add such standards.

ADUs Above a Detached Garage*
Currently, the zoning requirements prohibit ADUs to be built on top of existing detached garages or carports. This was allowed for the first few years of Glendale’s ADU/JADU Ordinance, however, in 2020 the Council amended the Ordinance to prohibit this type of ADU from being constructed. This change was in response to an increase in the number of complaints from residents regarding privacy issues. Government Code Section 66314(d)(3) allows ADUs to be attached to detached garages and HCD is asserting that the term “attached” would include an ADU built on top of an existing detached garage. The City maintains that neither the language nor intent of State law supports this claim. The referenced Government Code section mandates that the City allow an ADU to be attached to or located within the space of the primary dwelling (including attached garages and other areas that are attached), or mandates that the City allow an ADU to be converted from an accessory structure, or that the ADU be detached from the primary dwelling, including detached garages. The City allows all of these scenarios and staff contends that we are therefore in compliance and recommending that no amendments to the current ADU/JADU Ordinance be proposed.

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During the August 20, 2024 hearing, Councilmembers Brotman, Kasskhian and Asatryan were in favor of amending Title 30 and the DSP to address HCD’s claim regarding ADUs above a detached garage, along with objective design standards to minimize neighbor concerns such as privacy. Councilmembers Gharpetian and Najarian were in favor of not amending the ADU/JADU Ordinance and directed staff to draft the necessary findings in accordance with Government Code Section 66326 to continue to prohibit an ADU above a detached garage or carport (Exhibit 1). Based on Council direction, staff is providing an alternative in the draft ordinance to amend the referenced section, with the changes illustrated using bold italic underline strikeout. If this change is implemented, property owners would be able to construct ADUs on top of their detached garages and/or carports subject to the four-foot interior setback requirement, and 25-foot maximum height limit. A non-mandatory ADU would be subject to the objective design standards proposed with these amendments, which are intended to minimize privacy concerns by prohibiting balconies directly facing abutting properties and restricting the sill height on windows oriented towards abutting properties. However, as noted above, SB 1211 prohibits the City from imposing these same objective design standards on mandatory ADUs, so despite Council’s direction that staff allow ADUs above a detached garage with design standards, the new legislation prohibits these standards from applying to mandatory ADUs above a detached garage.

During the Planning Commission hearing on October 16, 2024, there was no general consensus regarding this topic. Commissioners Shahbazian and Minassian recommended that the City Council find that this portion of the current ordinance does not violate Government Code Section 66314(d)(3) and recommended Council adopt the required findings outlining the reasons why the City’s prohibition of ADUs above detached garages complies with State law. Commissioners Lee, Chraghchian, and Fuentes recommended that the City Council adopt the amendments to allow new construction ADUs above detached garages and two of the commissioners provided specific recommendations as noted below.
•Commissioner Lee recommended requiring applicants to demonstrate that there are no other site alternatives and that the new construction of an ADU directly above a detached garage is necessary to construct a mandatory ADU. •Commissioner Chraghchian recommended that the City look into ways to disincentivize the construction of ADUs above a detached garage in an effort to encourage property owners to pursue alternative solutions.

Parking
HCD identified one of the required parking exceptions for ADUs that is specified in State law and missing from the City’s ADU/JADU Ordinance. The exception would not require 438 of 559

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parking to be provided for the ADU when submitted with a permit application to build a new single-family dwelling or new multi-family dwelling, so long as the ADU satisfies other criteria in the sub-section. This was an oversight by the City to not include this exception and staff is proposing an amendment to GMC Section 30.34.080(H)(4)(h) to include this. Planning Commission concurred with Council’s August 20 direction to adopt this amendment.

Covenant and Agreement
Currently, all property owners developing an ADU and/or JADU on their property are required to enter into a covenant and agreement with the City regarding prohibition of individual sales, compliance with required parking, owner-occupancy restrictions on JADUs, short term rental prohibitions, that the permit runs with the land, and provisions for when the ADU and/or JADU must be removed. HCD contends that because State law does not require deed restrictions for ADUs, the City’s requirement for the Covenant and Agreement is in violation of State law. The City disagrees that simply because State law does not require a deed restriction for ADUs, it prohibits the City from requiring one.

However, the main reason for the ADU covenant is to ensure current and future owners would have notice of the owner-occupancy requirement for a property with an ADU, but this requirement was eliminated by State law effective January 2020. Accordingly, since the main purpose of the Covenant (notice of owner-occupancy requirement) has been eliminated, at Council direction staff is proposing amendments to GMC Section

30.34.080(I) to remove the requirement to enter into and record a covenant as a condition of approval of an ADU building permit application. In accordance with Government Code Section 66333(c), the covenant and agreement requirement will still be applicable to JADUs which continue to have an owner-occupancy requirement.

Planning Commission concurred with Council’s August 20 direction to adopt this amendment.

JADUs and Owner Occupancy
Pursuant to State law, the owner of a property with a JADU is required to live in either the JADU or the remaining portion of the residence. Government Code § 66333(b). The City’s ADU/JADU Ordinance, however, provides that if the owner does not live on-site, the property can only be rented as a whole (meaning that, though the owner does not have to live at the property, the residential dwelling and JADU cannot be rented separately to different renters). The City’s ADU/JADU Ordinance is more permissive than State law, which, again, requires owner-occupancy for properties with an existing JADU. The City’s position has been that a more permissive standard is allowed under State law. However, the plain language of Section 66333(b) requires owner-occupancy of properties with a JADU, and thus, staff is proposing amending GMC Section

30.34.080(I) to make this change to be consistent with State law, requiring an owner of 439 of 559

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a property with a JADU to live at the property. Planning Commission concurred with Council’s August 20 direction to adopt this amendment.

Additional Amendments and Miscellaneous Clean-Ups
Staff is also proposing amendments to GMC Section 30.34.080 to include additional definitions, provide an 800 SF credit for ADUs with respect to FAR and other such development standards, omit certain references to height and parking standards for underlying zones, and include a clarifying statement about compliance with state law.

The proposed amendments also include miscellaneous code clean-ups related to minor grammar and formatting, which do not change the substance or meaning of the text in any way.
•The following terms and definitions are proposed to be added to GMC Section

30.34.080(C) in order for the ADU/JADU Ordinance to be consistent with State law: livable space (from SB 1211 as noted above), nonconforming zoning condition, objective standards, passageway, proposed dwelling, and tandem parking.
•Current practice provides property owners with non-mandatory ADUs a credit towards lot coverage, landscaping, and floor area up to 800 SF to allow options for future development. Staff is proposing an amendment to GMC Section

30.34.080(D)(3) to codify this practice.
•The proposed amendments also include omitting references to ADU and JADU compliance with height and parking development standards for the underlying zone of the property. The provisions of the underlying zone do not apply for height and parking since Government Code Section 66321(b)(4) establishes standards for all mandatory and non-mandatory ADUs that supersedes any city requirements. The specified height requirements for all ADU and JADU projects ranges from 16 to 25 feet and will be depending on the location on-site (attached vs. detached) and proximity to major transit. As it relates to parking, the City’s underlying zoning standards are superseded by Government Code Section 66314(d)(10) which establishes the maximum parking requirements a city can impose on ADUs, and Government Code Section 66322 which establishes six instances where a city cannot impose any parking standards for an ADU. The City’s ADU/JADU Ordinance does address these requirements under state law, and our current practice is consistent with these requirements as well. The current references to height and parking in the context of the underlying zoning development standards that are found in portions of the ordinance conflict with this requirement and should be omitted for consistency with State law and the City’s current practice.
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•Staff is also proposing an amendment to the general provisions section of the ADU/JADU Ordinance (GMC Section 30.34.080(D)) to include a clarifying statement regarding compliance with the ADU and JADU permitting and processing requirements, mandates, timelines, deadlines, restrictions, prohibitions and limitations that are in State law.

PLANNING COMMISSION REVIEW
The proposed amendments were reviewed by the Planning Commission at a regularly scheduled meeting and hearing on October 16, 2024. All five commissioners were present. There was no testimony during the public comment portion of the hearing and staff received one comment letter from the Adams Hill Neighborhood Association which expressed support of staff’s recommendations and the proposed ordinances and cited concerns with the proliferation of ADUs and primary residences illegally being used as vacation rentals. A copy of this letter is included as Exhibit 3 to this report. For the majority of the proposed changes, the Planning Commission recommended adoption of the ordinances as presented and recommended by staff, including the proposed amendments related to the number of ADUs allowed (unit mix) and the proposed objective design standards. As noted in the sections above, the Planning Commission provided specific recommendations regarding where JADUs are permitted in the city, accessory living quarters, and ADUs above detached garages.

STAKEHOLDERS/OUTREACH
The Code requires public notice when the Council considers adoption of amendments to the Zoning Code and/or the General Plan. Staff has published all required notices for this hearing. Public notice was also provided for the Planning Commission hearing of October 16, 2024. Staff received one comment letter for that hearing from the Adams Hill Neighborhood Association (Exhibit 3), as noted above.

FISCAL IMPACT
There is no fiscal impact associated with this report.

ENVIRONMENTAL REVIEW (CEQA)
Pursuant to the California Environmental Quality Act (CEQA), staff has determined, and recommends that the City Council find, that the proposed amendments contained in the subject Ordinances and the accompanying Resolution are exempt from further review pursuant to Public Resources Code Section 21080.17 and California Code of 441 of 559

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Regulations, Title 14, Chapter 3, Section 15282(h) because the subject Ordinances and Resolution implement the provisions of former Government Code Sections 65852.2 and 65852.22 (now codified in Article 2 [commencing with Section 66314] and Article 3 [commencing with Section 66333] of Chapter 13 of Division 1 of Title 7 of, the Government Code), second units in a single-family or multifamily residential zone.

Moreover, the subject Ordinances and Resolution are exempt from further environmental review under CEQA pursuant to Title 14 of the California Code of Regulations Section 15060(c)(1), as they implement provisions of former Government Code Sections 65852.2 and 65852.22 (now codified in Article 2 [commencing with Section 66314] and Article 3 [commencing with Section 66333] of Chapter 13 of Division 1 of Title 7 of, the Government Code), which require ministerial review and approval of accessory dwelling units and junior accessory dwelling units and therefore, do not involve the exercise of discretionary powers by the City.

CAMPAIGN DISCLOSURE
This item is exempt from campaign disclosure requirements.

ALTERNATIVES TO STAFF RECOMMENDATION

1.Alternative 1: Not introduce and not subsequently adopt the proposed amendments to the Zoning Code and DSP which relate generally to standards for ADUs and JADUs.

This will likely cause HCD to escalate enforcement efforts that may expose the City to legal risks.

2.Alternative 2: Any other alternative not proposed by staff.

ADMINISTRATIVE ACTION
Submitted by:

Bradley Calvert, Director of Community Development
Prepared by:

Vista Ezzati, Principal Planner
Approved by:

Roubik R. Golanian, P.E., City Manager

EXHIBITS/ATTACHMENTS
Exhibit 1:City Council Motions, dated August 20, 2024
Exhibit 2:Planning Commission Motions, dated October 16, 2024 442 of 559

189a
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Exhibit 3:Planning Commission Public Comment Letter
Exhibit 4:ADU/JADU Matrix Regarding HCD Claims and City Responses 443 of 559

1 ORDINANCE NO. ________________

AN ORDINANCE OF THE CITY OF GLENDALE, CALIFORNIA
AMENDING SECTIONS 30.10.070, 30.11.020, 30.11.050, 30.12.020, 30.14.020, 30.15.020,

30.16.020, 30.34.080 and 30.70.050, OF TITLE 30
OF THE GLENDALE MUNICIPAL CODE, 1995,

RELATING TO ACCESSORY DWELLING UNITS AND JUNIOR ACCESSSORY DWELLING UNITS (CASE NO. PZC-0013-2024)
BE IT ORDAINED BY THE COUNCIL OF THE CITY OF GLENDALE:

WHEREAS, the City of Glendale (“City”) regulat es accessory dwelling units pursuant to Title 30 of the Glendale Munici pal Code, 1995 (“GMC”), including Chapter

30.34, as well as pursuant to the Glendale Building and Safety Code; and WHEREAS, California Government Code (“CA Gov’t Code”) Sections 66314, et seq., allow local agencies to enact ordinances providing for the creation of accessory dwelling units and ju nior accessory dwelling units, and es tablish standards for ministerial review of such units; and
WHEREAS, the City adopted Housing Element 2021-2029 of the General Plan on February 1, 2022 and this Element was certified by the State Department of Housing and Community Development (“HCD”) on February 27, 2023; and WHEREAS, CA Gov’t Code Section 66319 declares that accessory dwelling units in areas zoned to allow single-fam ily or multi-family dwelling residential uses do not exceed the allowable density for the lot upon which the accessory dwelling unit is located, and that accessory dwelling units are a residential use that is consis tent with the existing general plan and zoning designation for the lot; and
WHEREAS, the development of accessory dw elling units and junior accessory dwelling units will further local, regional and state goals for meeting the Regional Housing Needs Allocation set forth in the City’s Housing Element 2021-2029; and WHEREAS, the City’s Housing Element 2021-2029, contains Policy 1.9 “Encourage flexibility in the Zoning Ordinance to prom ote a wide range of housing types”; Policy 1.3 “Promote the dispersion of affordable housing throughout the City while recognizing the potential for the integrat ion of market-rate and affordable units within individual projects”; Policy 2.9 “Respect scale, historic continuity, and a sense of community in new residential development”; and, Policy 6.10 “encourage the use of sustainable building practices in residential developments” and permitted accesso ry dwelling units and junior accessory dwelling units implements these policies; and
WHEREAS, the Greener Glendale Plan for Co mmunity Activities was adopted by the City Council on March 12, 2012, for the purposes of promot ing sustainable practices and establishing greenhouse gas reduction stra tegies in accordance with AB 32 (2006) and SB 375 (2008); and
WHEREAS, the Greener Glendale Plan for Comm unity Activities Objective UD4 directs Glendale to continue to promote in fill development to increase sustainab ility and
444 of 559

2 livable environment and permitting accessory dwelling units and junior accessory dwelling units is consistent with that objective; and
WHEREAS, CA Gov’t Code Section 66314 require s cities to permit accessory dwelling units and junior accessory dwelling uni ts in areas zoned for single family and multifamily residential uses, but allows cities to designate areas where accessory dwelling units and junior accessory dwelling units may be permitted based on the adequacy of water and sewer services and the impact of accesso ry dwelling units and junior accessory dwelling units on traffic flow and public safety, as well as, allows cities to impose objective standards on accessory dwelling units that incl ude, but are not limited to, parking, height, setback, landscape, architectural review, maximum size of a unit, and standards that prevent adverse impacts on any real property t hat is listed in the California Register of Historical Resources; and
WHEREAS, on December 8, 2020, the City Council adopted Ordinance Nos. 5957 and 5958 amending permanent standards and processes for the review and approval of accessory dwelling units and junior accessory dwelling units, which Ordinance was codified in Section 30.34.080 of the GMC; and
WHEREAS, on November 15, 2022, the City Council adopted Ordinance No. 5997 incorporating state law amendments and minor modifications and clarifications related to accessory dwelling units and junior accessory dwelling units; and WHEREAS, following HCD’s review of Ordinance No. 5997, HCD sent the City a series of letters, commencing with a letter dated December 7, 2023, and including a June 19, 2024 “Notice of Violation” letter, with written findings alleging portions of Ordinance No, 5997 does not comply with CA Gov’t Code Sections 66314, et seq. (“State ADU Law”), to which the City responded; and
WHEREAS, pursuant to CA Gov’t Code Section 66326(b), the City must consider the findings made by HCD pursuant to its review of Ordinance No. 5997 and must either amend the Ordinance to comply with State ADU Law, and/or re-adopt the Ordinance without changes, but with findings in a resolution adopting the Ordinance that explains the reasons the City believes that the Ordinance complies with State ADU Law, despite HCD’s findings; and
WHEREAS, on August 20, 2024, at a regularly scheduled City Council meeting, and in response to the above-referenced writt en findings, the City Counc il considered said findings and initiated amendments to Title 30 of the GMC related to development standards for accessory dwelling units and junior accesso ry dwelling units as to portions of said findings, and directed staff to re-adopt Ordinance No. 5997 without changes (with findings in a resolution adopting the Ordinance expl aining the reasons the City believes the Ordinance complies with State ADU Law despite HCD’s findings) as to certain other portions of Ordinance No. 5997; and
WHEREAS, the City’s Planning Commissi on considered and recommended approval of these amendments to Title 30 of the GMC, as well as readoption of portions of Ordinance No. 5997 with findings, at its meeting of October 16, 2024. 445 of 559

3 NOW THEREFORE, THE CITY COUNCIL OF THE CITY OF GLENDALE DOES ORDAIN AS FOLLOWS:

SECTION 1. Findings.

The City Council finds, determines, and declares that:

1. The above recitals are true and correct and are incorporated herein by reference as if set forth in full.

2. All of the findings contained in Resolu tion No. ______ (A Resolution of the City Council of the City of Glendale, California, Making Findings That Certain Portions of Ordinance No. 5997 Complies With California Government Code Sections 66314, et seq., and 66333, et seq. Despite The Findings of the California Department of Housing and Community Development, Which Findings Are Required Pursuant to California Government Code Section 66326 Prior to Re-Adopting Those Portions of Ordinance No. 5997 Without Changes Within Ordinance No. ______) are hereby incorporated herein by reference as if set forth in full.

SECTION 2. Section 30.10.070 of the Glendale Municipal Code, 1995 is hereby amended to read as follows:

30.10.070 Zoning districts – Regulations.

A. Permitted Primary Uses and Structures. The purpose of the sectional listing of permitted primary uses and structures contained within each zone regulations is to identify all principal uses and structures that are allowable on a lot within that zone as a matter of right.

Subject to the provisions of the zone, except as otherwise provided, no building, structure or land shall be used and no building, structure or use shall be established except the listed permitted primary uses and structures.

B. Permitted Accessory Uses and Structures. The purpose of the sectional listing of permitted accessory uses and structures contained within each zone regulations is to identify uses and structures that are allowable when they are integrated with and clearly incidental to a primary use on the same lot. All buildings and structures shall conform to the development standards of the zone.

C. Temporary Uses and Structures. The purpose of the sectional listing of temporary uses and structures is to identify those uses that may be allowable within a given zone for a limited amount of time and under certain specified conditions.

D. Conditional Uses and Structures. The purpose of the sectional listing of conditional uses and structures is to identify those uses and structures which must first obtain permission for their establishment within the zone by a conditional use permit. The specific conditional uses and structures which are listed are considered to be typical of uses which require individual review as to their particular characteristics and location, and ones that may require special conditions to their establishment in order to protect the health, safety and general welfare.
446 of 559

4 E. Compliance with Laws. Notwithstanding any provision in this code to the contrary, any establishment that engages in or carries out any activity contrary to federal, state or local laws shall be prohibited.

F. Development Standards—General. The development standards contained within this title and the various zones have been established in order to assure adequate levels of light, air and density of development, to maintain and enhance locally-recognized values of community appearance and to promote the safe and efficient circulation of pedestrian and vehicular traffic. The standards are in furtherance of the goals and objectives of the comprehensive general plan and are found to be necessary for the preservation of the community, health, safety and general welfare.

G. Site Requirements—General. The area and dimensions of all building sites shall be sufficient to accommodate the anticipated density of development, open spaces, setbacks and parking spaces.

H. Density. The density of development has been established for each zone in accordance with the comprehensive general plan in order to promote the orderly, efficient and most appropriate growth within the city, consistent with the planned capability of services and infrastructures. Density shall be calculated from the area of the lot before any public right-of- way dedications are made. An accessory dwelling unit and/or junior accessory dwelling unit on a lot developed with single-family or multi-family dwelling unit(s) is deemed a residential use consistent with the existing general plan and zoning designation for the lot, as provided for in the Government Code of the State of California, Section 65852.266319.

I. Lot Size. Where minimum lot sizes or dimensions required within the zone standards, they have been established in order to promote the type and scale of development envisioned in the comprehensive general plan. Where existing lots with lesser size and dimensions are existing in a zone, an exception has been made in some zones for such lots when their development would not be harmful to the achievement of the overall goals and objectives of the plan.

J. Coverage. Maximum coverage requirements contained within certain zone standards have been established to provide minimum open spaces for light, air and ventilation and to reserve adequate area for open spaces, setbacks and other amenities. Coverage shall be calculated from the area of the lot after any public right-of- way dedications are made.

K. Height. Height standards are reflective of intensity and scale of development. In order to maintain a sound plan and compatibility with surrounding uses, the structural height of buildings must be regulated and intensities directed to their most appropriate location. Factors taken into consideration in the establishment of height criteria are shade/shadow effects; light, air and ventilation; scenic vistas; and intensity of development and ability to serve.

L. Unit Size. Minimum unit sizes as may be established in the various zones are for the purpose of assuring acceptable living areas, the control of overcrowding and the provision of conditions conducive to a decent, safe and sanitary environment.

M. Setbacks, Open Space and Landscaping Requirements. The purpose of setbacks, 447 of 559

5 open space and landscaping requirements is to assure that an effective separation is provided between properties and uses to foster compatibility, identity, privacy, light, air and ventilation and provide for landscaped areas in the living and working environments for visual relief and recreation. Setbacks and required landscaping shall be calculated from the property lines or area of the lot after any public right-of-way dedications are made.

N. Medical Marijuana Dispensary, Marijuana Dispensary, Marijuana Cultivation, Marijuana Processing, and Delivery or Distribution of Marijuana or Medical Cannabis Products as Prohibited Uses. Notwithstanding any other provision of this code, a medical marijuana dispensary, marijuana dispensary, marijuana cultivation, marijuana processing, and delivery or distribution of marijuana or medical cannabis products, as these terms are defined in Section 9.10.010, are prohibited in all zones, including all specific plan areas, except where the city is preempted by federal or state law from enacting a prohibition of any such prohibited uses, or is preempted by federal or state law from enforcing any of these prohibitions.

O. Home-Sharing Activities and Vacation Rentals. Home-sharing, as defined in Section

5.56.030, is permitted subject to the restrictions in Chapter 5.56. Vacation rentals, as defined in Section 5.56.030, are prohibited in all zones.

SECTION 3. Section 30.11.020 of the Glendale Municipal Code, 1995 is hereby amended to read as follows:

30.11.020 Residential district land uses and permit requirements.

A. Permitted Primary Uses and Structures. No building, structure or land shall be used and no building, structure or use in the residential zoning districts shall be erected, structurally altered, enlarged or established except the following permitted uses, buildings and structures identified with a “P” in Table 30.11–A.

B. Conditional Uses and Structures. The following uses and structures identified with a “C” in Table 30.11 – A may be permitted in the residential zoning districts subject to approval of a conditional use permit (Section 30.42). The development standards of this zone shall apply except as otherwise provided herein.

C. Temporary Uses. Temporary uses (identified with a “T” in Table 30.11 – A), allowed subject to approval and compliance with all applicable provisions of this Zoning Code.

D. Permitted Accessory Uses and Structures. Accessory uses, buildings and structures shall be permitted in zones identified with a “P” in Table 30.11 – A.

E. Wireless Telecommunications Facilities. Wireless telecommunications facilities, identified with a “W” in Table 30.11-A may be permitted subject to the approval of a wireless telecommunications facility permit as set forth in Chapter 30.48 of this code.

F. Standards for Specific Uses. Where the last column in the following tables (“See standards in Section”) includes a section number, the regulations in the referenced section apply to the use; however, provisions in other sections of this Zoning Code may apply as well.

G. Historic Resources. Uses listed as permitted or conditionally permitted within a historic resource included on the Glendale Historic Register only (identified in Table 30.11 – A) are 448 of 559

6 permitted or conditionally permitted only within a designated historic resource on the Glendale Register of Historic Resources.

Table 30.11-A

RESIDENTIAL DISTRICTS AND PERMIT REQUIREMENTS

LAND USE (1)(2)
PERMIT REQUIREMENT BY ZONE See
Standards
in Section
or Chapter ROS R1R R1 R3050 R2250 R1650 R1250
Residential Uses
Domestic violence shelter P P P P P P P
Multiple residential dwellings P P P P 30.11.050
One residential dwelling per lot P P P P P P P 30.34.110 Residential congregate living,
limited

P P P P P P P
Residential congregate living,
medical
C C C
Residential congregate living,
non-medical

C C C C
Senior housing P P P P
Education, Public Assembly, Recreation
Community gardens P P P P P P P 30.34.045
Day care center, only where
operated at a church,
synagogue, temple, or other
house of worship, religiously
affiliated or nonsectarian
preschool. In determining
whether to grant or deny a
conditional use permit for a day
care center hereunder, the
content of any curriculum and
every aspect of an organization’s
operations which are religious in
nature shall not be considered

C C C C
Parks and playgrounds,
operated by a homeowners’
association and approved in
connection with a subdivision

P P P P P P P
Parks and playgrounds, private C C C C C C C
Parks and playgrounds, public P P P P P P P
449 of 559

7 LAND USE (1)(2)
PERMIT REQUIREMENT BY ZONE See
Standards
in Section
or Chapter ROS R1R R1 R3050 R2250 R1650 R1250
Places of worship C C C C C C C
Schools, private C C C
Open Space and Resources
Open space P P P
Transportation and Communication Uses
Utility and transmission facilities C C C C C C C
Wireless telecommunication
facilities
W W W W W W W 30.48
Accessory Buildings, Structures and Uses
Accessory dwelling unit (ADU)
and/or junior accessory
dwelling unit (JADU) on a lot
developed with one residential
dwelling unit
P P P P P P P 30.34.080
Accessory dwelling unit(s) (ADU)
on a lot developed with more
than one residential dwelling unit
P P P P P P P 30.34.080
Accessory living quarters or
guest house not to exceed an
aggregate area of 500 sq. ft. of
floor area

P P P P P P P
Accessory buildings or
structures, other than garages or
carports, not to exceed 500 sq.
ft. of floor area

P P P P P P P
Accessory uses P P P P P P P
Antennas (pole type) P P P P P P P
Dish antennas P P P P P P P 30.34.050
Home occupations P P P P P P P 30.45
Home-sharing P P P P P P P 5.110
Junior accessory dwelling unit
on a lot developed with one
residential dwelling unit
P P P 30.34.080
Signs P P P P P P P 30.33
Solar energy equipment P P P P P P P 30.30.050
Temporary Uses
450 of 559

8 Key to Permit Requirements Symbol See Chapter
Permitted use P

LAND USE (1)(2)
PERMIT REQUIREMENT BY ZONE See
Standards
in Section
or Chapter ROS R1R R1 R3050 R2250 R1650 R1250
Contractor’s office and/or
storage, temporary

T T T T T T T
Temporary subdivision sales
offices, sales trailers and model
dwellings or trailers proposed for
use as temporary sales offices
shall be registered with the
director of community
development by an application
for conditions of use. The
director of community
development may establish
conditions for operations and
maintenance, including, but not
limited to, restrictions on hours
of operation, lighting and
promotional restrictions and
reasonable termination of the
temporary use. The decision of
the director of community
development shall be
appealable.

T T T T T T T
Uses Within a Historic Resource
Cultural art centers C C C C C C C
Day care centers C C C C C C C
Museum C C C C C C C
Office C C C C C C C
Residential congregate living,
non-medical
C C C
Restaurants, full service not to
exceed a seating capacity of 40
persons

C C C C
Retail stores, general
merchandise

C C C C C C C
Schools, physical instruction C C C C C C C
Schools, private specialized
education and training

C C C C C C C
451 of 559

9 Key to Permit Requirements Symbol See Chapter
Conditional use—Conditional use permit required C 30.42 Temporary use T

Wireless telecommunications facilities permit required W 30.48 Use not allowed

Notes:
(1) See Section 30.03.010 regarding uses not listed.

(2) See Chapter 30.70 for definitions of the land uses.

SECTION 4. Section 30.11.050 of the Glendale Municipal Code, 1995 is hereby amended to read as follows:

30.11.050 Residential district additional R-3050, R-2250, R-1650 and R-1250 development standards. The following standards shall apply in the R-3050, R-2250, R-1650, and R-1250 zones.

A. Dwelling Unit Size. The gross floor area of any dwelling unit shall be not less than provided herein. For the purpose of this section, dens, studies or other similar rooms which may be used as bedrooms shall be considered as bedrooms. Living rooms, dining rooms, kitchens, or bathrooms shall not be considered as bedrooms except that separate dining rooms in efficiency units or rooms that could be converted into additional bedrooms shall be considered as bedrooms. This development standard does not apply to or govern dwelling unit size for accessory dwelling units or junior accessory dwelling units, which are defined separately in Section 30.34.080.

1. Efficiency and one bedroom units: 600 square feet.

2. Two bedroom units: 800 square feet.

3. Three or more bedroom units: 1,000 square feet.

B. Private Outdoor Space. A minimum private outdoor space of 40 square feet shall be provided for each dwelling unit. Such private outdoor space shall be designed as a patio, deck, or balcony and shall have a minimum length or width of four feet and shall be directly accessible and an integral part of the dwelling unit which it serves.

C. Common Outdoor Space. A minimum common outdoor space of 200 square feet shall be provided per dwelling unit for the first 25 dwelling units on a lot; a minimum common outdoor space of 150 square feet shall be provided per dwelling unit for the second 25 dwelling units on a lot; a minimum common outdoor space of 100 square feet shall be provided per dwelling unit for each additional dwelling unit above 50 on a lot. Any common outdoor space shall have a minimum level surface dimension of 10 feet and a minimum area of 200 square feet.

Landscaping and seating shall be permanently integrated into all required common outdoor spaces. No street front setback area or street side setback area shall be used for common outdoor space. The developer shall pay an amount of money, established by the city council 452 of 559

10 as a parks fee, to be used by the city for the purpose of fulfillment of recreational demand created by the project.

D. Distance Between Dwellings. Exterior walls of separate buildings containing dwelling units on the same lot shall be separated by a minimum distance of 12 feet. The windows or window/doors of any one dwelling unit may not face the windows or window/doors of any other dwelling unit unless separated by a distance of 12 or more feet except where the angle between the wall of the separate dwelling units is 90 degrees or more. Walls parallel to each other shall be considered to be at a zero degree angle.

E. Rooftop Equipment. For regulations concerning rooftop equipment, see Section

30.30.020 of this title.

F. Fences and Walls. For regulations concerning fences and walls, see Chapter Section

30.30.010.

G. Trash Collection Areas. For regulations concerning trash collection areas, see Chapter Section 30.30.030.

H. Access to Dwelling Units. An elevator shall be provided to serve all stories in a building containing more than three dwelling units where the floor area of any dwelling unit is located only on the third story and other dwelling units are located on the first and second stories.

I. Laundry Facilities. Laundry facilities shall be provided to serve all dwelling units on a lot.

Such laundry facilities, constituting washer and dryer appliances connected to utilities, shall be provided in the individual dwelling units where there are three or less dwelling units on a lot.

Where there are more than three dwelling units on a lot, laundry facilities shall either be provided in the individual dwelling units or in a common laundry room. A common laundry room shall be in an accessible location and shall have at least one washer and one dryer for each 10 dwelling units, maintained in operable condition and accessible to all tenants daily between the hours of 7:00 a.m. and 10:00 p.m.

J. Storage Space-Private. A minimum of 90 cubic feet of private storage space shall be provided for each dwelling unit outside such unit unless a private attached garage serving only the dwelling unit is provided. Such private storage space shall have a minimum horizontal surface area of 24 square feet and shall be fully enclosed and lockable.

K. Additional Standards for Floor Area Ratio Minimums.

1. Any development of three to seven multiple residential dwelling units shall not have a floor area ratio standard that is less than 1.0.

2. Any development of eight to 10 multiple residential dwelling units shall not have a floor area ratio standard that is less than 1.25.

3. To be eligible for the provisions in subsections (K)(1) and (K)(2) above, a multi-family housing development project shall meet all of the following conditions:
a. The project consists of at least three, but not more than 10, units. b. The project is located in a multi-family residential zone, commercial zone, or a mixed-use zone, and is not located in either of the following:
i. Within a single-family zone.
ii. Within a historic district or property that is included on the State Historic Resources Inventory, as defined in Section 5020.1 of the Public Resources 453 of 559

11 Code, or within a site that is or contains buildings, sites, objects, structures, neighborhoods, cultural landscapes, and archaeological sites, that are designated or listed as a city or county landmark or historic property or district pursuant to a city or county ordinance.

4. This subsection shall not be construed to prohibit the city from imposing any zoning or design standards, including, but not limited to, building height and setbacks, on a housing development project that meets the requirements of this subsection, other than zoning or design standards that establish floor area ratios or lot size requirements that expressly conflict with the standards contained in this subsection.

5. The city may not impose a lot coverage requirement that would physically preclude a housing development project that meets the requirements of this subsection from achieving the floor area ratio allowed herein.

SECTION 5. Section 30.12.020 of the Glendale Municipal Code, 1995 is hereby amended to read as follows:

30.12.020 Commercial district land uses and requirements.

A. Permitted Primary Uses and Structures. No building, structure or land shall be used and no building, structure or use in the commercial zoning districts shall be erected, structurally altered, enlarged or established except the following permitted uses, buildings and structures identified with a “P” in Table 30.12-A.

B. Conditional Uses and Structures. The following uses and structures identified with a “C” in Table 30.12-A may be permitted in the commercial zoning districts subject to approval of a conditional use permit (Chapter 30.42). The development standards of this zone shall apply except as otherwise provided herein.

C. Administrative Uses and Structures. The following uses and structures identified with an “A” in Table 30.12-A may be permitted in the commercial zoning districts subject to approval of an administrative use permit (Chapter 30.49). The development standards of this zone shall apply except as otherwise provided herein.

D. Temporary Uses. Temporary uses (identified with a “T” in Table 30.12-A), allowed subject to approval and compliance with all applicable provisions of this Zoning Code.

E. Permitted Accessory Uses and Structures. Accessory uses, buildings and structures shall be permitted in zones identifies with a “P” in Table 30.12A.

F. Wireless Telecommunications Facilities. Wireless telecommunications facilities, identified with a “W” in Table 30.12-A may be permitted subject to the approval of a wireless telecommunications facility permit as set forth in Chapter 30.48 of this code.

G. Standards for Specific Uses. Where the last column in the following tables (“See Standards in Chapter or Section”) includes a Chapter or Section number, the regulations in the referenced chapter or section apply to the use; however, provisions in other sections of this Zoning Code may apply as well.

H. Uses Not Listed. Land uses that are not listed on Table 30.12-A, or are not shown in a particular zoning district are not allowed, except for other uses which the director of community 454 of 559

12 development determines to be similar in nature, function and operation to listed permitted primary uses within these zones.

Table 30.12-A

COMMERCIAL DISTRICTS AND PERMIT REQUIREMENTS
LAND USE (1)(2)
PERMIT REQUIREMENT BY ZONE See
Standards in
Chapter or
Section

C1 C2 C3 CR CPD CH CA
Accessory Structures and Uses
Accessory dwelling unit (ADU), and/or
junior accessory dwelling unit (JADU)
on a lot developed with one residential
dwelling unit
P P P P P P P 30.34.080
Accessory dwelling unit(s) (ADU) on a
lot developed with more than one
residential dwelling unit
P P P P P P P 30.34.080
Accessory uses P P P P P P P
Antennas (pole type) and flagpoles P P P P P P P
Carts (freestanding, non-motorized,
portable type) P P P P P P 30.34.040
Dish antennas P P P P P P P 30.34.050
Home occupations P P P P P 30.45
Home-sharing P P P P P P P 5.56
Reverse vending machines P P P P P P 30.12.040
Signs P P P P P P P 30.33
Solar energy equipment P P P P P P P 30.30.050
Institutional Uses
Cultural arts centers P P P
Hospitals P P
Museums P P P
Places of worship P P P C P
Schools, physical instruction P P P P P
Schools, private C C C C C
Schools, private specialized education
and training A P P C P
Light Industrial Uses
Backlots/outdoor facilities—Production C C
Broadcasting studios and indoor support
facilities—Production P P P(3) P
Medical and dental laboratories P P P(3) P
Soundstages—Production P P
Utility and transmission facilities C C C C C C C
Miscellaneous Uses
Non-emergency heliports C C
455 of 559

13 LAND USE (1)(2)
PERMIT REQUIREMENT BY ZONE See
Standards in
Chapter or
Section

C1 C2 C3 CR CPD CH CA
Parking lots or structures P P P P P P P 30.32

30.51.020
Office Uses
Contractors office and/or storage,
temporary T T T T T T T
Contractors office P P P P P P
Medical and dental offices P P P P(3) P P P
Office P P P P(3) P P P
Office, consumer services P P P
Veterinary offices, including
hospitalization services P P P P P
Recreational Uses
Arcade establishment C C C
Billiard establishments P P P P
Children’s indoor play areas P P P P
Community gardens P P P P P P 30.34.045
Cyber-café establishments P P A
Gyms and health clubs P P C P P
Indoor recreation center P P P P P
Outdoor commercial recreation C C
Private clubs and lodges C C P C P
Public dances P P P P P P
Taverns C C C C C C
Theaters C P C P
Residential Uses
Domestic violence shelters P P P P P P
Emergency shelter C C C
Residential congregate living, limited
subject to the provisions of one
residential dwelling per lot in the R-1250
zone

P P P P P P

Residential congregate living, medical A P P P
Residential congregate living, non-
medical, subject to the provisions of the
R-1250 zone and provided further that
ground floor level is occupied with
permitted commercial uses

P P P P

Residential congregate living, non-
medical, at the ground floor level subject
to the provisions of the R-1250 zone

A A A A

Multiple residential dwellings subject to
the provisions of the R-1250 zone and
provided further that the ground floor

P P P P P

456 of 559

14 LAND USE (1)(2)
PERMIT REQUIREMENT BY ZONE See
Standards in
Chapter or
Section

C1 C2 C3 CR CPD CH CA
level is occupied with permitted
commercial uses
Multiple residential dwellings with
dwelling units at the ground floor level
subject to provisions of the R-1250 zone

C C C C
One residential dwelling per lot subject
to the provisions of the R-1250 zone P P P P P P
Senior housing subject to the provisions
of the R-1250 zone and provided further
that the ground floor level is occupied
with permitted commercial uses

P P P P P
Senior housing at the ground floor level
subject to the provision of the R-1250
zone

C C C C C
Retail Uses
Alcoholic beverage sales A(4) A(4) A(4) A(4) A(4) A(4) Automobile supply store P P P P P
Banquet halls C C C C
Christmas tree sales lots, when
maintained between November 1st and
January 9th
T T T T T 5.36
Firearms, weapon sales P P P P
Hardware stores P P P P P P
Jewelry stores P P P P P P
Liquor stores A A A A A A
Nurseries and garden supplies P P P P P
Paint and wallpaper stores P P P P P P
Pawnshops P P
Pharmacy P P P P P P
Pumpkin sales lots, when maintained
between October 15th and November 1st T T T T T 5.36 Restaurant, counter service with limited
seating P P P P P P
Restaurants, fast food A P P A P P
Restaurants, full service P P P P P P
Retail stores, general merchandise P P P P P P
Spas and swimming pools, sales and
service P P P P P
Supermarkets P P P P P P
Vehicle sales, leasing and rental
agencies P P P 30.34.160
Service Uses
Ambulance services P P P P P P
457 of 559

15 LAND USE (1)(2)
PERMIT REQUIREMENT BY ZONE See
Standards in
Chapter or
Section

C1 C2 C3 CR CPD CH CA
Banks and financial institutions P P P P P P
Business support services P P P P(3) P P
Car washes, full or self service P P P P 30.34.030 Day care centers P P P P P P P
Gas station C P P C P P 30.34.020
Heating and air conditioning sales and
service (HVAC) P P 30.34.070
Hotels and motels P P P(3) P
Massage establishment C C C C C C 5.64
Mortuaries and funeral homes P P
Personal services P P P P P P
Pet grooming P P P P P
Repair and maintenance, consumer
products P P P P P P
Tire stores P P P 30.34.140
Vehicle repair garage P P P 30.34.150
Wireless telecommunications facilities W W W W W W W 30.48

SECTION 6. Section 30.14.020 of the Glendale Municipal Code, 1995 is hereby amended to read as follows:
458 of 559

16 30.14.020 Mixed use district land uses and permit requirements.

A. Permitted Primary Uses and Structures. No building, structure or land shall be used and no building, structure or use in the mixed-use zoning districts shall be erected, structurally altered, enlarged or established except the following permitted uses, buildings and structures identified with a “P” in Table 30.14-A.

B. Conditional Uses and Structures. The following uses and structures identified with a “C” in Table 30.14-A may be permitted in the mixed-use zoning districts subject to approval of a conditional use permit (Chapter 30.42). The development standards of this zone shall apply except as otherwise provided herein.

C. Administrative Uses and Structures. The following uses and structures identified with an “A” in Table 30.14-A may be permitted in the commercial zoning districts subject to approval of an administrative use permit (Chapter 30.49). The development standards of this zone shall apply except as otherwise provided herein.

D. Temporary Uses. Temporary uses (identified with a “T” in Table 30.14-A), allowed subject to approval and compliance with all applicable provisions of this Zoning Code.

E. Permitted Accessory Uses and Structures. Accessory uses, buildings and structures shall be permitted in zones identified with a “P” in Table 30.14-A.

F. Wireless Telecommunications Facilities. Wireless telecommunications facilities, identified with a “W” in Table 30.14-A may be permitted subject to the approval of a wireless telecommunications facility permit as set forth in Chapter 30.48 of this code.

G. Standards for Specific Uses. Where the last column in the following tables (“See Standards in Section or Chapter”) includes a section number, the regulations in the referenced section apply to the use; however, provisions in other sections of this Zoning Code may apply as well.

Table 30.14-A

MIXED USE ZONING DISTRICTS AND PERMIT REQUIREMENTS
LAND USE (1)(2)

PERMIT REQUIREMENT

BY ZONE
See Standards
in Section or
Chapter IMU IMU-R SFMU
Accessory Buildings, Structures and Uses
Accessory dwelling unit (ADU), and/or junior
accessory dwelling unit (JADU) on a lot
developed with one residential dwelling unit
P P 30.34.080
Accessory dwelling unit(s) (ADU) on a lot
developed with more than one residential
dwelling unit
P P 30.34.080
Accessory buildings and structures P P
Accessory uses P P P
459 of 559

17 LAND USE (1)(2)

PERMIT REQUIREMENT

BY ZONE
See Standards
in Section or
Chapter IMU IMU-R SFMU
Antennas (pole type) P P P
Carts (freestanding, non-motorized, portable
type) P P P 30.34.040
Dish antennas P P P 30.34.050
Home occupation P P 30.45
Home-sharing P P P 5.110
Reverse vending machines P P P 30.14.040
Signs P P P 30.33
Solar energy equipment P P P 30.30.050
Institutional Uses
Places of worship C C C
Schools, physical instruction P P P
Schools, private C C C
Schools, private specialized education and
training P P P
Recreation
Community gardens P P P 30.34.045
Gyms and health clubs C C C
Indoor recreation centers C C C
Nightclubs C
Outdoor commercial recreation C C C
Private clubs and lodges C C C
Public dances P P P
Taverns C C C
Theaters C C C
Manufacturing and Processing
Backlots/outdoor facilities—Production P C C
Broadcasting studios and indoor support
facilities—Production P P P
Heavy manufacturing P P
Laundries and dry-cleaning plants P P(4)
Light manufacturing P P P(3)(4)
Printing, publishing, and lithographic services P P(4) P(3)(4) Research and development P P P(4)
Soundstages—Production P P C
Warehousing P P P(4)
Wholesaling, including wholesaling of alcoholic
beverages P P P(4)
Residential Uses
Domestic violence shelter P P P
Conversion of a live/work unit to entirely
residential or entirely business use C C C
Emergency shelter P
460 of 559

18 LAND USE (1)(2)

PERMIT REQUIREMENT

BY ZONE
See Standards
in Section or
Chapter IMU IMU-R SFMU
Multiple residential dwelling units A P(5)
Residential congregate living, limited P
Residential congregate living, medical A A
Residential congregate living, non-medical A A
Senior housing C P(5)
Mixed-Use Developments
Live/work units A A P(6) 30.34.090
Live/work units with conditionally permitted uses C C C(6) 30.34.090 Mixed-use development provided that all uses
are permitted in zone which the project is
located
P(6) 30.34.100
Mixed-use development where at least one use
is conditionally permitted C(8) C C 30.34.100
Retail Trade Uses
Alcoholic beverage sales A(9) A(9) A(9)
Automobile supply stores P P
Banquet halls C C
Building materials, supplies, sales and service P P
Christmas tree sales lots, when maintained
between November 1st and January 9th T T 5.36
Firearms, weapon sales P P
Hardware stores P P
Jewelry stores P P P
Liquor stores A A A
Nurseries and garden supplies P P P
Paint and wallpaper stores P P
Pharmacy P P P
Pumpkin sales lots, when maintained between
October 15th and November 1st T T 5.36
Restaurant, counter service with limited seating P P P
Restaurants, fast food P P P
Restaurants, full service P P P
Retail stores, general merchandise P P P
Spas and swimming pools, sales and service P P
Supermarkets P P P
Vehicle sales, leasing and rental agencies,
including new and used automobiles,
motorcycles, light trucks, recreational vehicles
and boats
P P 30.34.160
Vehicle sales, leasing and rental agencies,
including new and used automobiles,
motorcycles, light trucks, recreational vehicles
and boats existing prior to September 12, 2006,
P 30.34.160
461 of 559

19 LAND USE (1)(2)

PERMIT REQUIREMENT

BY ZONE
See Standards
in Section or
Chapter IMU IMU-R SFMU
including a one-time expansion on the same lot
of up to 20% of floor area
Expansion of vehicle sales, leasing and rental
agencies, including new and used automobiles,
motorcycles, light trucks, recreational vehicles
and boats existing prior to September 12, 2006,
when proposed expansion is on the same lot as
the existing facility and is greater than 20% of
the floor area existing prior to September 12,
2006, or for any new facilities on separate or
non-contiguous lots
C 30.34.160
Service Uses
Ambulance services P P
Banks and financial institutions P P P
Body shops and painting booths P P(4) 30.34.150
Business support services P P P
Car washes (full or self service) P P 30.34.030
Day care centers P P A
Equipment rental yards P P
Gas stations P P C 30.34.020
Heating and air conditioning sales and service
(HVAC) P P 30.34.070
Hotel and motels C C C
Kennel, animal boarding and daycare P(10) P(10)
Massage establishment C C C 5.64
Medical and dental laboratories P P P
Mortuaries and funeral homes A A
Moving and storage services P P
Pawnshops P P P
Personal services P P P
Pet grooming P P
Repair and maintenance, consumer products P P(4) P(3)(4)(11) Storage, personal facility P
Storage, outdoor facility P
Tire stores P P 30.34.140
Towing services and impound yards C C 30.34.145
Vehicle repair garages P P(4) 30.34.150
Office Uses
Contractor’s office and/or storage, temporary T T
Medical and dental offices P P P
Offices P P P
Office, consumer services P P C
Veterinary offices, including hospitalization
services P P
462 of 559

20 LAND USE (1)(2)

PERMIT REQUIREMENT

BY ZONE
See Standards
in Section or
Chapter IMU IMU-R SFMU
Transportation and Communications Uses
Parking lot/structure facilities P P C 30.32, 30.51.020 Utility and transmission facilities C C C
Wireless telecommunications facilities W W W 30.48

Key to Permit Requirements Symbol See Chapter
Permitted use P
Administrative use—Administrative use permit
required A 30.49
Conditional use—Conditi onal use permit required C 30.42 Temporary use T
Wireless telecommunications facilities permit
required W 30.48
Use not allowed
Notes:
(1) See Section 30.03.010 regarding uses not listed. (2) See Chapter 30.70 for definitions of the land uses. (3) If gross floor area of the building is 10,000 sq. ft. or less and use is indoors; if greater than 10,000 sq. ft. and/or use is outdoors, a conditional use permit is required. (4) Requires a conditional use permit when combined in a mixed-use development which includes residential.
(5) When fronting San Fernando Road, Broadway, or Colorado Street, only allowed as mixed-use projects with commercial uses located along the street frontage as required in Section 30.34.100.
(6) For lots having frontage along San Fernando Road, Broadway, and Colorado Street, manufacturing and processing uses shall not be on the ground floor fronting these streets. (7) No drive-thru facilities permitted.
(8) The only dwelling units permitted are live/work units. (9) Supermarkets only require an Administrative Use Permit for on-site consumption of alcoholic beverages. An Administrative Use Permit is not required for wholesaling. (10) Not to be located nearer than 200 feet to the R1, R1R, ROS, R-3050, R-2250, R-16-50 and R-1250 zones if use includes outdoor facilities.
(11) For upholstery services it shall include furniture only, no vehicles. 463 of 559

21 SECTION 7. Section 30.15.020 of the Glendale Municipal Code, 1995 is hereby amended to read as follows:

30.15.020 Special purpose district land uses and permit requirements.

A. Permitted Primary Uses and Structures. No building, structure or land shall be used and no building, structure or use in the special purpose zoning districts shall be erected, structurally altered, enlarged, or established except the following permitted uses, buildings and structures identified with a "P" in Table 30.15-A.

B. Conditional Uses and Structures. The following uses and structures identified with a "C" in Table 30.15-A may be permitted in the special purpose zoning districts subject to approval of a conditional use permit (Chapter 30.42). The development standards of this zone shall apply except as otherwise provided herein.

C. Administrative Uses and Structures. The following uses and structures identified with an “A” in Table 30.15-A may be permitted in the special purpose zoning districts subject to approval of an administrative use permit (Chapter 30.49). The development standards of this zone shall apply except as otherwise provided herein.

D. Temporary Uses. Temporary uses (identified with a “T” in Table 30.15-A), allowed subject to approval and compliance with all applicable provisions of this Zoning Code.

E. Permitted Accessory Uses and Structures. Accessory uses, buildings and structures shall be permitted in zones identified with a “P” in Table 30.15-A.

F. Wireless Telecommunications Facilities. Wireless telecommunications facilities, identified with a “W” in Table 30.15-A, may be permitted subject to the approval of a wireless telecommunications facility permit as set forth in Chapter 30.48 of this code.

I. Uses Not Listed. In the CE and CEM zones only, land uses that are not listed on Table

30.15-A, or are not shown in a particular zoning district are not allowed, except where other uses which the directory of community development determines to be similar in nature, function and operation to listed permitted primary uses within these zones.

Table 30.15-A

SPECIAL PURPOSE DISTRICTS AND PERMIT REQUIREMENTS
LAND USE (1)(2)
PERMIT

REQUIREMENT BY
ZONE See Standards in
Section or
Chapter CE CEM MS SR
Accessory Buildings, Structures and Uses
464 of 559

22 LAND USE (1)(2)
PERMIT

REQUIREMENT BY
ZONE See Standards in
Section or
Chapter CE CEM MS SR
Accessory dwelling unit (ADU), and/or junior
accessory dwelling unit (JADU) on a lot
developed with one residential dwelling unit

30.34.080
Accessory dwelling unit(s) (ADU), on a lot
developed with more than one residential
dwelling unit

30.34.080
Accessory use P P P P

Accessory living quarters or guest house not to
exceed an aggregate area of 500 sq. ft. of floor
area

Antennas (pole type) and flagpoles P P P P

Auditoriums

P P

Caretaker's residences P P P P

Carts (freestanding, nonmotorized, portable
type)

P P 30.34.040
Dish antennas P

P P 30.32.050
Home occupations

Home-sharing

5.56 Manufacturing of containers for caskets,
remains and flowers

Mobile medical trailers, temporary

T(5)

Museums

Nurseries and garden supplies

Reverse vending machines

30.12.040
Signs P P P P 30.33
Solar energy equipment P P P P 30.30.050
Agriculture, Open Space, and Resources
Apiaries

Open space/conservation areas

Education, Public Assembly, Recreation—General
Amphitheaters

Aquariums

Arboretums and botanical gardens

Auditoriums

Aviaries

Bandstands

465 of 559

23 LAND USE (1)(2)
PERMIT

REQUIREMENT BY
ZONE See Standards in
Section or
Chapter CE CEM MS SR
Community gardens

P P

Golf courses, country clubs, driving ranges and
related facilities

Libraries

Local fairs

Museums

Observatories

Parks and playgrounds, private

P P

Places of worship

P P(4)

Public dances

Recreational camps

Riding academies or stables

P(3)

Stables, including boarding of horses, sale or
exchange of horses and horse rentals
P

Swimming pools

Education, Public Assembly, Recreation Within a Public Park Amphitheaters

Aquariums

Arboretums and botanical gardens

Auditoriums

Aviaries

Bandstands

Community center

Community gardens

P 30.34.045
Convention centers

Day care

Golf courses, country clubs, driving ranges and
related facilities

Gymnasiums

Libraries

Local fairs

Museums

Observatories

Parks and playgrounds, public

Public dances

466 of 559

24 LAND USE (1)(2)
PERMIT

REQUIREMENT BY
ZONE See Standards in
Section or
Chapter CE CEM MS SR
Recreational camps

Riding academies or stables

P(3)

Swimming pools

Institutional Uses
Cultural arts centers

Hospitals

Museums

Schools, physical instruction

Schools, private

Schools, private specialized education and
training

Light Industrial Uses
Broadcasting studios and indoor support
facilities—Productions

Medical and dental laboratories

Miscellaneous Uses
Non-emergency heliport

Parking lots

Parking structures, subject to PS overlay
required setback standards

30.23,

30.32.110
Office Uses
Contractor's office and/or storage, temporary T

T T

Contractor's office

Medical and dental offices

Office

Office, consumer services

Recreational Uses
Children indoor play areas

Cyber-café establishments

Gyms and health clubs

Indoor recreation center

Private clubs and lodges

Residential Uses
Domestic violence shelter

Emergency shelter

467 of 559

25 LAND USE (1)(2)
PERMIT

REQUIREMENT BY
ZONE See Standards in
Section or
Chapter CE CEM MS SR
Multiple residential dwelling units subject to
provisions of the R-2250 zone

One residential dwelling per lot subject to
provisions of the R-2250 zone

Residential congregate care living, limited

Residential congregate care living, medical

Residential congregate care living, non-medical

Senior housing

Retail Uses
Alcoholic beverage sales

A A

Christmas tree sales lots, when maintained
between November 1st and January 9th
T

5.36 Jewelry stores

Liquor stores

Pharmacy

Pumpkin sales lots, when maintained between
October 15th and November 1st
T

5.36 Restaurant, counter service with limited seating

Restaurants, fast food

Restaurants, full service

Retail stores, general merchandise

Western retail and supply stores P

Service Uses
Ambulance services

Banks and financial institutions

Business support services

Cemeteries

Day care centers

Gas station

30.34.020
Hotels and motels

Kennel and animal boarding P

Massage establishment

5.64 Mortuaries and funeral homes

Personal services

Repair and maintenance, consumer products

468 of 559

26 LAND USE (1)(2)
PERMIT

REQUIREMENT BY
ZONE See Standards in
Section or
Chapter CE CEM MS SR
Sanitary landfills and related recovery of
materials

Transportation and Communications Uses
Utility and transmission facilities C C C(6) C

Wireless telecommunication facilities W W W W 30.48

(2) See Chapter 30.70 for definitions of the land uses. (3) Not to be located nearer than 1/2 mile to the R1, R1R, ROS, R-3050, R-2250, R-1650 and R-1250 zones on which there is no H overlay zone.
(4) Places of worship in the SR zone must have been in existence as of September 26, 2006.
(5) Temporary mobile medical trailers must be used on a hospital site and are limited to a period of 2 years.
(6) See Section 30.15.060 for additional standards.

SECTION 8. Section 30.16.020 of the Glendale Municipal Code, 1995 is hereby amended to read as follows:

30.16.020 TOD district land uses and permit requirements.

A. Permitted Primary Uses and Structures. No building, structure or land shall be used and no building, structure or use in the transit oriented development districts shall be erected, structurally altered, enlarged, or established except the following permitted uses, buildings and structures identified with a "P" in Table 30.16.020-A.

469 of 559

27 B. Conditional Uses and Structures. The following uses and structures identified with a "C" in Table 30.16.020-A may be permitted in the transit oriented development districts subject to approval of a conditional use permit (Chapter 30.42). The development standards of this zone shall apply except as otherwise provided herein.

C. Administrative Uses and Structures. The following uses and structures identified with an “A” in Table 30.16.020-A may be permitted in the transit oriented development districts subject to approval of an administrative use permit (Chapter 30.49). The development standards of this zone shall apply except as otherwise provided herein.

D. Temporary Uses. Temporary uses (identified with a “T” in Table 30.16.020-A), allowed subject to approval and compliance with all applicable provisions of this Zoning Code.

E. Permitted Accessory Uses and Structures. Accessory uses, buildings and structures shall be permitted in zones identified with a “P” in Table 30.16.020-A.

F. Wireless Telecommunications Facilities. Wireless telecommunications facilities, identified with a “W” in Table 30.16-A, may be permitted subject to the approval of a wireless telecommunications facility permit as set forth in Chapter 30.48 of this code.

Table 30.16.020-A

TRANSIT ORIENTED DEVELOPMENT DISTRICTS AND PERMIT REQUIREMENTS

LAND USE (1)(2)

PERMIT REQUIREMENT
BY ZONE See Standards
in Section or
Chapter TOD I TOD II
Accessory Buildings, Structures and Uses
Accessory dwelling unit (ADU), and/or junior
accessory dwelling unit (JADU) on a lot
developed with one residential dwelling unit
P P 30.34.080
Accessory dwelling unit (ADU), on a lot
developed with one residential dwellin
g unit
P P 30.34.080
Accessory uses P P

Accessory buildings and structures P P

Antennas (pole type) and flagpoles P P

Carts (freestanding, non-motorized, portable
t
ype)
P P 30.34.040
Dish antennas P P 30.34.050
470 of 559

28 LAND USE (1)(2)

PERMIT REQUIREMENT
BY ZONE See Standards
in Section or
Chapter TOD I TOD II
Home occupation P P 30.45
Home-sharing P P 5.110
Reverse vending machines P P 30.12.040
Signs P P 30.33
Solar energy equipment P P 30.30.050
Institutional Uses
Hospitals

Places of worship C

Schools, physical instruction P C

Schools, private C

Schools, private specialized education, and
training
P C

Recreation
Arcade establishment P P

Billiard establishments P

Community gardens P

30.34.045
Gyms and health clubs P

Indoor recreation center C

Outdoor commercial recreation C

Private clubs and lodges C

Public dances P

Taverns C

Theaters P P

Manufacturing and Processing
Backlots/outdoor facilities – production C

Broadcasting studios and indoor support
facilities
– production
P

Heavy manufacturing, if existing prior to
October 10, 2023
P P

Laundries and dry cleaning plants, if existing
prior to October 10, 2023
P P

Light manufacturing P (3)(4)

Medical and dental laboratories P P

Printing, publishing, and lithographic services P (3)(4)

Research and development P(4)

471 of 559

29 LAND USE (1)(2)

PERMIT REQUIREMENT
BY ZONE See Standards
in Section or
Chapter TOD I TOD II
Soundstages – production P

Warehousing P

Wholesaling, including wholesaling of alcoholic
beverages
P

Residential Uses
Domestic violence shelters P P

Conversion of a live/work unit to entirely
residential or entirely business use
A

Emergency shelter C

Multiple residential dwelling units P(5) P (5)

Residential congregate living, Limited (subject
to the provisions of one residential dwelling per
lot
)
P P

Residential congregate living, Medical P P

Residential congregate living, Non-medical P (5) P (5)

One residential dwelling per lot subject to the
provisions of the R-1250 zone
P

Senior housing P (5) P (5)

Mixed-Use Developments
Live/work units P(6)

30.34.090
Live/work units with conditionally permitted
uses
C

30.34.090
Mixed-use development provided that all uses
are permitted in zone which the project is
located
P P

Mixed-use development where at least one use
is conditionally permitted
C C

Retail Trade Uses
Alcoholic beverage sales A(8) A(8)

Automobile supply store P

Banquet halls C

Building materials, supplies, sales and service P

Christmas tree sales lots, when maintained
between November 1
st and January 9th
T T 5.36
Jewelry stores P

Liquor stores A

472 of 559

30 LAND USE (1)(2)

PERMIT REQUIREMENT
BY ZONE See Standards
in Section or
Chapter TOD I TOD II
Nurseries and garden supplies P

Paint and wallpaper stores P

Pawnshops, if existing prior to October 10,
2023
P

Pharmacy P P

Pumpkin sales lots, when maintained between
October 15th and November 1st
T T 5.36
Restaurant, counter service with limited seating P P

Restaurants, fast food P P

Restaurants, full service P P

Retail stores, general merchandise P P

Supermarkets P P

Vehicle sales, leasing and rental agencies,
including new and used automobiles,
motorcycles, light trucks, recreational vehicles
and boats existing prior to October 10, 2023,
including a one-time expansion on the same lot
of up to 20 percent of floor area.

30.34.160
Expansion of vehicle sales, leasing and rental
agencies, including new and used automobiles,
motorcycles, light trucks, recreational vehicles
and boats existing prior to September 12, 2006,
when proposed expansion is on the same lot as
the existing facility and is greater than 20
percent of the floor area existing prior to
September 12, 2006, or for any new facilities
on separate or non-conti
guous lots.

30.34.160
Service Uses
Banks and financial institutions P

Body shops and painting booths, if existing
prior to October 10, 2023

30.34.150
Business support services P

Day care centers A A

Equipment rental yards, if existing prior to
October 10, 2023
P

Gas station P

30.34.020
Heating and air conditioning sales and service
(HVAC), if existing prior to October 10, 2023
P

30.34.070
473 of 559

31 LAND USE (1)(2)

PERMIT REQUIREMENT
BY ZONE See Standards
in Section or
Chapter TOD I TOD II
Hotels and motels P

Kennel, animal boarding and daycare P (9)

Massage establishment C

5.64 Medical and dental laboratories P P

Mortuaries and funeral homes A

Moving and storage services, if existing prior to
October 10, 2023
P

Personal Services P P

Pet grooming P

Repair and maintenance, consumer products P (4)

Tire stores, if existing prior to October 10, 2023

30.34.140
Vehicle repair garage, if existing prior to
October 10, 2023
P

30.34.150
Office Uses
Contractors office and/or storage, temporary T T

Medical and dental offices P P

Office P P

Office, consumer services C

Veterinary offices, including hospitalization
services
P

Transportation and Communications Uses
Parking lot/structure facilities C P 30.32,

30.51.020
Utility and transmission facilities C C

Wireless telecommunications facilities W W 30.48

32 (1) See Section 30.03.010 regarding uses not listed. (2) See Chapter 30.70 for definitions of the land uses. (3) If gross floor area of the building is 10,000 sq. ft. or less and use is indoors; if greater than 10,000 sq. ft. and/or use is outdoors, a conditional use permit is required. (4) Requires a conditional use permit when combined in a mixed-use development which includes residential.
(5) When fronting San Fernando Road, Central Avenue, or Los Feliz Road, only allowed as mixed-use projects with commercial uses located along the street frontage as required in Section 30.34.100.
(6) For lots having frontage along San Fernando Road, Central Avenue, or Los Feliz Road, manufacturing and processing uses shall not be on the ground floor fronting these streets. (7) No drive-thru facilities permitted.
(8) Supermarkets only require an AUP Administrative Use Permit for on-site consumption of alcoholic beverages. Administrative Use Permit for on-site consumption of alcoholic beverages. An Administrative Use Permit is CUP not required for wholesaling. (9) Not to be located nearer than 200 feet to the R1, R1R, ROS, R-3050, R-2250, R16-50 and R-1250 zones if use includes outdoor facilities.

SECTION 9. Section 30.34.080 of the Glendale Municipal Code, 1995 is hereby amended to read as follows:

30.34.080 Accessory dwelling units and junior accessory dwelling units.

A. Intent and Purpose. This section is intended to provide for the creation of accessory dwelling units and junior accessory dwelling units in a manner that is ministerial and nondiscretionary consistent with state law.

1. Accessory dwelling units and/or junior accessory dwelling units, as applicable, are located on lots developed or proposed with dwelling units in areas zoned for single- family and multi-family residential (including mixed-use residential) uses and can provide an important source of affordable housing. For purposes of this section, the existing one residential dwelling on property zoned single-family residential or property with an existing single-family dwelling on it shall also be known as the primary dwelling.

2. Accessory dwelling units and junior a ccessory dwelling units, when appropriately sized and located, have little impact on neighborhood quality of life or upon real property that is listed, or identified on a historic survey as potentially eligible on the National Register of Historic Places, California Register of Historical Resources, Glendale Register of Historic Resources, and in a city of Glendale designated or nominated Historic District.

3. Establishing reasonable regulations for accessory dwelling units and junior 475 of 559

33 accessory dwelling units is an appropriate mechanism to properly balance the need for additional affordable housing with the need to maintain existing architectural character, community character and neighborhood quality of life.

4. Accessory dwelling units and junior accessory dwelling units are not considered for purposes of general plan density calculation.

5. Accessory dwelling unit and junior accessory dwelling unit permits are necessary to enable tracking of affordable housing and to ensure review and compliance with zoning, fire, and life safety standards contained in state and local law.

Glendale City CouncilNovember 19, 2024

Glendale City Council
November 19, 2024