Redwood Coast Energy Authority Board of Directors
September 24, 2026

Board of Directors Regular Meeting Agenda
Wharfinger Building, Bay Room (downstairs)
1 Marina Way, Eureka, CA 95501
Thursday, September 24 2026
3:30 PM
Meeting Information
Meeting Reports and Comments
Pursuant to Government Code section 54957.5, all writings or documents relating to any item on this agenda which have been provided to a majority of the Board, including those received less than 72 hours prior to the Board’s meeting, will be made available to the public at redwoodenergy.org.

Speakers wishing to distribute materials to the Board at the meeting must provide 13 copies to the Board Clerk.

How to Participate
This is a hybrid in-person and virtual meeting. When technical difficulties arise that prevent members of the public from offering comments, or if broadcasting is disrupted due to matters out of RCEA’s control, this meeting will be discontinued unless otherwise allowed by law.

To participate in the meeting online, go to https://us02web.zoom.us/j/81972368051.

To participate by phone, call (669) 900-6833 or (253) 215-8782. Enter webinar ID: 819 7236 8051.

To speak during the public comment periods, raise your hand in the online Zoom webinar, or press star (*) 9 on your phone to raise your hand. Staff will ask you to unmute your phone or computer when it is your turn. You will have 3 minutes to speak.

Email written comments to [email protected]. Identify the agenda item number in the subject line. Comments will be included in the meeting record but not read aloud during the meeting.

Accessibility
Need help with accessibility? Any member of the public needing special accommodation to participate in this meeting or access the meeting materials should email [email protected] or call (707) 269-1700 at least 3 business days before the meeting. Assistive listening devices are available. 1 September 24, 2026
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Open Session (Call to Order)

1. Roll Call | Remote Director Participation

1.1. Brown Act Teleconference Participation Rules

2. Reports from Member Entities

3. Oral & Written Communications
This time is provided for people to address the Board or submit written communications on matters not on the agenda. At the conclusion of all oral communications, the Board may respond to statements. Any request that requires Board action will be set by the Board for a future agenda or referred to staff.

4. Staff Reports

4.1. Executive Director’s Report

5. Consent Calendar
All matters in the Consent Calendar section are considered routine by the Board and are enacted in one motion. There is no separate discussion of any of these items; if discussion is required, that item is removed from the Consent Calendar and considered separately. At the end of the reading of the Consent Calendar, Board members or members of the public can request that an item be removed for separate discussion.

5.1. Approve Minutes of August 27, 2026, Board Meeting.

5.2. Accept Disbursement Report for July 2026, and Financial Reports for This Fiscal Year Through July 2026.

6. Items Removed from Consent Calendar
Items removed from the Consent Calendar section will be heard under this section.

Community Choice Energy (CCE) Business
Items under this section of the agenda relate to CCE-specific business matters that fall under RCEA’s CCE voting provisions, with only CCE-participating jurisdictions voting on these matters with weighted voting as established in the RCEA joint powers agreement.

7. CCE Business Consent Calendar
All matters in the Community Choice Energy Business Consent Calendar section are considered routine by the CCE-participating jurisdiction Board members and are enacted in one motion. There is no separate discussion of any of these items. If discussion is required, that item is removed from the Consent Calendar section and considered separately. At the end of the reading of the CCE Business Consent Calendar, any Board member or members of the public can request that an item be removed for separate discussion.

7.1. Adopt Resolution 2026-10 Approving and Attesting to the Veracity of RCEA’s 2025 Power Source Disclosure Report.

8. Items Removed from CCE Business Calendar
Items removed from the Consent Calendar section will be heard under this section. 2 September 24, 2026
RCEA Board of Directors Meeting Agenda
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9. Old CCE Business – None.

10. New CCE Business – None.

End of CCE Business | Resume RCEA Board Business

11. Old Business

11.1. Annual Humboldt Sawmill Company Alternative Biomass Use Report (Information only)

11.2. Grid Resilience Innovation Partnership (GRIP) Program Funds for Tribal Energy Resilience and Sovereignty Project Final Award Execution and Staffing Authorize RCEA Executive Director to execute the Department of Energy Grid Resilience Innovation Partnership Program Funds for Tribal Energy Resilience and Sovereignty Project GD-0000967 Final Award and Unfreeze the Contracts and Grants Manager Upon Execution of Final Award.

12. New Business

12.1. Regional Climate Action Plan: Establishing RCEA as Host Agency Approve the Memorandum of Understanding establishing RCEA as the host agency for the Regional Climate Committee and Climate Program Manager Position to coordinate the implementation of the Regional Climate Action Plan.

12.2. Approval of Fifth Lease Amendment Between GHD, Tenant, and RCEA, Landlord, for 718 3rd Street, Eureka, CA
Approve Fifth Amendment to Commercial Lease Agreement between Redwood Coast Energy Authority, Landlord, and GHD Inc., Tenant, for 718 3rd Street and Authorize the Executive Director to execute all applicable documents pending review by RCEA Legal Counsel.

12.3. Recommended Design-Build Procurement for 718 3rd Street Office Remodel Authorize RCEA’s Executive Director to utilize the design-build process to procure design and construction of the commercial remodel and improvements to 718 3rd St. Eureka; and initiate the first step by developing and issuing a Request for Qualifications.

Create an Ad Hoc Building Remodel Solicitation Committee comprised of five or fewer RCEA Board members.

Delegate authority to the Building Remodel Solicitation Ad Hoc Committee to: 1) approve the short list of qualified design build contractors, and 2) authorize the Executive Director to issue a Request for Proposals for construction of the commercial remodel/improvements at 718 and 720 3rd St. Eureka.

12.4. Overview of Distributed Energy Resources and Virtual Power Plants (Information only) 3 September 24, 2026
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13. Future Agenda Items
Any request that requires Board action will be set by the Board for a future agenda or referred to staff.

14. Adjournment
Next Regular Meeting
Thursday, October 22, 2026 | 3:30 PM
Wharfinger Building Bay Room (downstairs), 1 Marina Way, Eureka, CA 95501 Online and phone participation is available via Zoom.
4

Staff Report
Agenda Item # 1.1
Information
Agenda Date August 27, 2026
To Board of Directors
Prepared by Eileen Verbeck, Deputy Executive Director
Subject Revised Member Teleconference Participation Rules Background
When emergency Brown Act meeting law changes went into effect in 2020 due to the COVID-19 public health emergency, the RCEA Board of Directors, Community Advisory Committee (CAC) and the subcommittees of those bodies met online via teleconference using the Zoom platform with no physical, public meeting location. Since the pandemic, the Brown Act has been amended to codify modern teleconference meeting practices both during and outside of declared states of emergency. SB 707 (Durazo, 2025) sets out the latest Brown Act revisions which were signed into law on October 3, 3025.

Summary
RCEA Board Directors may attend up to two meetings per year from a remote location without making the location accessible to the public for the following, revised, “just cause” reasons:

1. Childcare or caregiving to child, parent, grandparent, grandchild, sibling, spouse, domestic partner;

2. Contagious illness that prevents in person attendance;

3. Mental or physical need not subject to reasonable accommodation provisions;

4. Travel while on official business of RCEA or another state or local agency;

5. Immunocompromised child, parent, grandparent, grandchild, sibling, spouse, or domestic partner that requires remote participation;

6. Physical or family medical emergency; or

7. Military service obligations.

A vote is not necessary to request remote attendance for just cause, including for medical emergency remote attendance per SB 707 revisions. A brief description, protecting the Director’s (or family member’s) medical privacy, must be provided and the Director must publicly disclose whether anyone 18 years of age or older is present in the room at the remote location, and the general nature of the individual’s relationship with the Director.

At a future meeting, staff will recommend Board adoption of a revised Teleconferencing Policy capturing the latest Brown Act revisions and provide the Board an opportunity to pass a resolution enabling remote meeting participation for members who must travel at least 20 miles to the Wharfinger Building. 5

Staff Recommendation
None. Information only.

Required Distribution Information
The Revised Ralph M. Brown Act
Link to California Government Code Sections 54950 - 549631, revised October 3, 2025, by SB 707 (Durazo, 2025).

Redwood Coast Energy Authority List of Physical Meeting Locations Body Date Time Location
Board of Directors 4th Thursday of each
month 3:30 p.m. Wharfinger Building, 1 Marina Way, Eureka, CA 95501 Community Advisory
Committee
2nd Tuesday of odd-numbered months 6 p.m.

Jefferson Community Center
Auditorium, 1000 B Street, Eureka,
CA 95501
Finance Committee As needed, dates TBD TBD RCEA Offices, 633 Third Street, Eureka, CA 95501
1 The Revised Ralph M. Brown Act, California Code, GOV 54950.5 - 54963:
https://leginfo.legislature.ca.gov/faces/codes_displayText.xhtml?lawCode=GOV&division=2.&title=5.&part=1.&chapt er=9.&article=
6

Staff Report
Agenda Item # 4.1
Information
Agenda Date September 24, 2026
To Board of Directors
Prepared by Elizabeth Burks, Executive Director
Subject Executive Directors’ Report
Summary
Executive Director Elizabeth Burks will provide updates on topics as needed.

RCEA Updates
August Customer Contact Log Summary
In August 2026, there were 135 total customer-initiated interactions (107 phone calls, 11 lobby walk-ins, 17 emails).

The top categories for inquiries were:
• Rebate/Customer Programs – 43
• Billing – 25
• Net Energy Metering (NEM) – 23
Rebate & Customer Program Inquiries
Of the month’s program inquiries, 40% were related to e-bike vouchers, 26% about EV incentives, and 9% about heat pump rebates. Billing inquiries primarily involved questions about electric bills, energy usage, and overall costs, while Net Energy Metering (NEM) inquiries focused on imports and exports, solar system performance, and understanding NEM and Solar Billing Plan statements following completion of the annual cash-out process.

Note: There were a total of six opt outs for the month of August.

NREN Update
In August, the RCEA Northern Rural Energy Network team completed nine home energy assessments, gave out 26 efficiency kits, and paid out $7,780 in rebates to Humboldt County customers. 7

NREN Partner
Rebates Efficiency Kits Energy Assessments
August YTD August YTD August YTD
RCEA $7,780 $86,230 26 263 9 59
LAPC $1,742 $6,565 10 407 5 37
MCOG $100 $6,503 42 193 5 33
SBC $15,794 $68,405 40 453 5 56
Total $25,416 $167,703 118 1316 24 185
Staff Recommendation
None. Information only.

Attachments

1. Community Outreach Events Summary

2. LEAN/Community Choice Energy Alliance Federal Activity Report - August 2026 8 In October, we’ll staff education tables at
Friends of the Lost Coast’s Natural Science
Day in Garberville, Fortuna Apple Harvest
Festival and Walk to End Alzheimer’s event.

We participated in a variety of community
events, including hosting NREN’s Energy
Incentives Pre-Launch Open House, and
staffing tables at the Loleta Community
Resource Center, Bridgeville Community
Resource Center and two days at the North
Country Fair.

Events Next Month
Redwood Coast
Energy Authority –
Community Outreach
& Events Summary
September 2026

AT A GLANCE
Each month, RCEA connects with
community members across Humboldt
County through events, presentations, and
outreach efforts that build awareness of our
programs and services. This summary
provides a snapshot of our outreach reach,
engagement highlights, and upcoming
opportunities to connect with the
community.
9 August 2026
By Community Choice Energy Alliance
Download PDF Version
Executive Summary
Congress spent most of August in their districts, however, they did make progress on several priorities. Prior to adjourning for recess, the Senate introduced and passed a stopgap spending bill that would fund the federal government through Dec. 11, which the House also passed upon returning to session. The Senate also introduced a Budget Resolution for “Reconciliation 3.0,” but failed to vote on the measure before adjourning.

Other legislative work also hit roadblocks before recess, as Senate negotiators continued struggling to reach a permitting reform deal, pushing the timeline for a deal back to September.

Congress will return in September with numerous priorities to address and limited time left on the legislative calendar.

While Congress was in recess, the administration remained active. President Trump signed an Executive order prohibiting some foreign bulk-power system electrical equipment and software.

Interior Secretary Doug Burgum issued a Secretarial order to speed up the department’s historical preservation reviews for projects on federal land. The administration also began circulating draft legislation addressing its spent nuclear fuel plans and released the first details on the Energy Star Program’s transition to the Department of Energy.

In judicial news, a District Court judge granted a preliminary injunction intended to prevent the Environmental Protection Agency from submitting more clean air waivers to Congress for nullification.

CCEA FEDERAL ADVOCACY
CCEA submitted comments to the Department of Energy (DOE) Notice of Proposed Rulemaking on the Energy Conservation Program: Procedures, Interpretations, and Policies for 10 Consideration of New or Revised Energy Conservation Standards and Test Procedures for Consumer Products and Certain Commercial/Industrial Equipment (“Process Rule”).

CONGRESSIONAL ACTIONS

1. Congress Approves Stopgap Bill Extending Government Funding Through Dec. 11
The House returned from its August recess on Aug. 31 for the September work period, with a top priority of extending government funding beyond the Sept. 30 deadline. In July, the House and Senate each passed differing Continuing Resolutions (CRs) to fund the government. On Sept. 1, the House passed the Senate-approved stopgap funding bill by a vote of 370-48. The CR extends government funding through Dec. 11 and temporarily reauthorizes surface transportation programs. The CR also delays implementation of proposed rulemaking by the Office of Management and Budget to change the administration of federal grants and awards, for which CCEA advocated. President Trump signed the CR into law on Sept. 2.

When Congress returns in November, it will again need to address FY27 spending, requiring a significant effort given that the Senate has not passed any of its 12 appropriations bills and the House has passed only three bills.

2. Senate Releases Budget Resolution for Reconciliation 3.0 Prior to adjourning for August recess on Aug. 7, Senate Budget Committee Chair Ron Johnson (R-WI)released a Budget Resolution for “Reconciliation 3.0” that includes instructions for new energy spending. The Resolution, which is broader than the version the House passed in July and was not acted on by the Senate before recess, includes spending instructions for eleven committees. The Senate Energy and Natural Resources Committee would be allowed to increase the deficit by up to $1 billionover the next ten years, while neither the Environment and Public Works Committee nor the Finance Committee were included in the budget framework. The resolution also includes several of the same funding priorities from the House resolution, including farm assistance, defense spending, and election-related funding. Shortly after the budget resolution was introduced, the Senate entered its month-long August recess without voting on the resolution.

3. Senate Permitting Reform Deal Elusive
On Aug. 4,Senate permitting reform negotiators held a closed-door meeting to discuss the state of talks and announced that a deal is now expected in September. The negotiators, consisting of Environment and Public Works Committee (EPW) Chair Shelley Moore Capito (R-WV) and Ranking Member Sheldon Whitehouse (D-RI), and Energy and Natural Resources (ENR) Chair Mike Lee (R-UT) and Ranking Member Martin Heinrich (D-NM), met after weeks of staff-level talks to discuss the timeline of a deal and the remaining issues to be solved. The new September timeline is a change from previous statements, where negotiators hadstatedtheir goal to release a permitting reform deal before leaving for August recess. Sens. Capito and Whitehouse both stated their continued optimism about reaching a deal. According to an aide that was in attendance, many of the unresolved issues are within the jurisdiction of ENR, although the aide also stated that the two committees are still planning to release a single reform package. While there is limited time for reaching a permitting reform deal and passing legislation this congress, Senate Majority Leader John Thune (R-SD) has stated that he would prioritize floor time for permitting reform following August recess. 11 ADMINISTRATION ACTIONS

4. President Trump Signs Executive Order Prohibiting Some Foreign Bulk-Power Electrical Equipment
On Aug. 26, President Trump signed an Executive order titled “Declaring a National Emergency to Secure the United States Bulk-Power System.” The order prohibits the acquisition, importation, transfer, or installation of any foreign-produced electric equipment, critical component, or software if it is found to have been developed or supplied by a Covered Foreign Entity or otherwise poses a national security risk. The Secretary of Energy, in coordination with the Secretaries of War, Commerce, Homeland Security, and the Director of National Intelligence, is given responsibility for determining what products pose such national security risks, as well as imposing conditions for the continued use of products already acquired or installed in the bulk-power system. The order cites increased activity from foreign actors exploiting vulnerabilities in the bulk-power system, and the limited restrictions on importation and use of foreign-produced bulk-power equipment, as reasons for declaring the national emergency and implementing new restrictions. Following President Trump’s signing, the Department of Energy has 120 days to publish rules and regulations for implementing the order. CCEA is closely monitoring the rulemaking process and coordinating with national trade groups to assess potential implications for CCAs and keep members informed as implementation develops.

5. Administration Circulates Draft Nuclear Waste Legislation The Trump administration is circulating draft legislation to support its proposed Nuclear Lifecycle Innovation Campuses (NLIC). The “Nuclear Reindustrialization Act of 2026” would require the Department of Energy (DOE) to prioritize NLICs for carrying out the federal government’s responsibility to dispose of spent nuclear fuel, and repeal sections of the Nuclear Waste Policy Act that designated Yucca Mountain as the sole repository DOE site. These campuses would provide for the storage, disposal, and reprocessing of spent nuclear fuel. In July, DOE had announced Oklahoma, Louisiana, Idaho, Tennessee, and Utah as finalists to host these NLICs. The bill also proposes allowing DOE to use the Nuclear Waste Fund for any activities undertaken at the NLICs, as well as restarting the collection of fees for the Nuclear Waste Fund. Finally, the draft bill would formally disband the Nuclear Waste Technical Review Board, which advises DOE’s spent nuclear fuel program, and saw all but one of its members fired by President Trump in July 2025. While Members of Congress broadly support the administration’s plan to address nuclear waste, several have raised concerns about provisions such as use of the Nuclear Waste Fund and lack of oversight, underscoring that the draft legislation still needs buy-in from Capitol Hill.

6. Sec. Burgum Issues Order to Speed Historic Preservation Reviews
Interior Secretary Doug Burgum issued aSecretarial orderto speed up historical preservation reviews for projects on federal land. Theorder instructs agency officials to process Section 106 reviews ina timely and efficient manner, identifyproject categories that have no potential to cause effects on historic properties for exemption from review, and implement program alternatives for a more flexible approach to conducting reviews.

Additionally, the order requires officials to implement existing efficiencies, such as 30-day deadlines and coordination with the National Environmental Policy Act review process, and to strive for a 180-day resolution timeline when projects are found to have an adverse effect on historic properties. The Interior Department argues that the changes within this order will allow the Department to consider effects on historic properties more meaningfully, as well as efficiently, while requiring states and tribes to do so as well. The order comes as the Trump administration is considering significant changes to historic reviews, which were 12 proposed by the Advisory Council on Historic Preservation and seeks to speed approvals for energy projects.

7. Federal Agencies Publish Energy Star Transition Plan On Aug. 28, the Environmental Protection Agency (EPA) and Department of Energy (DOE) published its long-awaited plan to transition the Energy Star program from EPA to DOE. In March, the two federal agencies signed a Memorandum of Agreement (MOA) for the formal transition. The Transition Plan reaffirms both agencies’ commitment to a smooth transition and to minimizing any disruptions to the 1,500 manufacturers, 1,200 retailers, 840 utilities, and $100 billion in private markets that use the Energy Star program. The plan outlines three major workstreams for the transition, including knowledge transfer and consolidation of leadership, transfer of legal and trademark agreements, and transfer of IT systems and data. The workstreams will be phased, with the full transition targeted for completion by July 2027.

The plan states that the transition will be funded through FY26 appropriations and that the long-term success of the program depends on adequate funding by Congress.

JUDICIAL ACTIONS

8. Judge Blocks EPA from Submitting Clean Air Waivers for Congressional Review Act
On Sept. 2, U.S. District Court Senior Judge Beryl Howell blocked the Environmental Protection Agency (EPA) from sending California Clean Air Act Waivers to Congress for nullification under the Congressional Review Act (CRA). In June, EPA sent four California waivers, which dated as far back as 2009 and covered clean car rules and the electrification of small engines such as those found in lawn equipment, to Congress for review and nullification under the CRA.

California then sued the EPA, arguing that the agency had unlawfully reclassified the waivers as rules prior to sending them to Congress. Judge Howell granted a preliminary injunction to California stating that the waivers were not rules when issued, therefore EPA either took formal action under the Administrative Procedure Act to reclassify the waivers as rules or misled Congress by sending reports that called the waivers rules. Howell’s strongly worded decision condemned EPA’s use of CRA to nullify waivers, arguing that it undermines “honest compliance with the law.” The preliminary injunction prevents EPA from reclassifying additional waivers as rules subject to CRA but cannot stop Congress from voting to nullify the waivers already submitted, as legislation has already been introduced. Howell does, however, order EPA to attempt to restore the status quo from before it sent the waivers to Congress and to withdraw or correct other waiver reclassifications. While no announcements have yet been made, the Trump administration is expected to appeal the order.

Additional Resources
Log in to CCEA's Members-Only Portal to access:

A detailed Members Directory
Federal Policy Committee documents and materials (log in to read all weekly and monthly reports, policy briefs, and additional resources)
CCEA’s curated national CCA database (for Terawatt members only) 13 Community Choice Energy Alliance partners with Meguire Whitney to advance federal policy and advocacy for CCAs.

Visit our Website
Community Choice Energy Alliance | 2108 N ST # 8586 | Sacramento, CA 95816 US Unsubscribe | Update Profile | Constant Contact Data Notice 14 Board of Directors Draft Meeting Minutes
Wharfinger Building, Bay Room (downstairs)
1 Marina Way, Eureka, CA 95501
Thursday, August 27 2026
3:30 PM
Attendance
Present
Scott Bauer Sarah Schaefer, Vice Chair
Carlos Diaz Jack Tuttle
Michael Gerace, Chair Frank Wilson
Skip Jorgensen Mike Wilson
Elise Scafani
Absent
Jason Ramos
Staff and Others Present
Name Title
Ken Beals Information Technology Technician
Elizabeth Burks Executive Director
Faith Carlson Regulatory & Legislative Manager
Nancy Diamond RCEA Legal Counsel
Richard Engel Power Resources Director
Stephen Kullmann Customer Programs Director
Lori Taketa Board Clerk
Eileen Verbeck Deputy Executive Director
15 8/27/26
RCEA Board of Directors DRAFT Minutes
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Open Session (Call to Order)
Chair Gerace called a meeting of the Board of Directors of the Redwood Coast Energy Authority to order at the above location and date at 3:33 p.m. Notice of this meeting was posted on August 21, 2026.

4. Staff Reports

4.1. Executive Director’s Report
Executive Director Burks reported on staff’s successful application for $2.9 million in investment tax credits for the Redwood Coast Airport microgrid. The RCEA electricity rate will change on September 1.

Nine customers opted out so far due to the rate change, roughly the same number as in other months.

Staff are discussing the rate change at member jurisdiction meetings. Recruitment continues for the Director of Engagement and Regional Climate Planning and staff General Counsel positions.

Regulatory and Legislative Manager Carlson reported on Power Charge Indifference Adjustment (PCIA) legislation and regulatory proceedings. The California Public Utilities Commission decided that Community Choice Aggregators’ (CCAs’) customers will not benefit from pre-2019 banked Renewable Energy Credits despite having paid for them prior to becoming CCA customers. In the Legislature, the PCIA Data Transparency Bill passed both houses and awaits the Governor’s signature. There were no public comments.

5. Consent Calendar

5.1. Approve Minutes of July 23, 2026, Board Meeting.

5.2. Approve Disbursement Reports for June 2026, and Financial Reports for this Fiscal Year through June 2026.

5.3. Enter into an Agreement for Professional Services Between the Redwood Coast Energy Authority and Owsley Electric Inc. for Electrical Services at the Redwood Coast Airport Microgrid for a Term up to Five (5) Years and a Total Not to Exceed of $325,000 and Authorize the Executive Director to Execute All Applicable Documents Pending Review by RCEA Legal Counsel.

5.4. Approve Waiver of Potential Conflict of Interest and Provide Informed Consent Regarding Counsel Representation by the Law Offices of Nancy Diamond on Redwood Coast Energy Authority's Interests in the Regional Climate Action Plan.

There were no requests to remove items from the consent calendar, nor public comments.

M/S: M. Wilson, Tuttle: Approve Consent Calendar items.

The motion passed with a unanimous voice vote. Ayes: Bauer, Diaz, Gerace, Jorgensen, Scafani, Schaefer, Tuttle, F. Wilson, M. Wilson. Noes: None. Absent: Ramos. Abstain: None.

9. Presentations

9.1. Presentation on RCEA’s Customer Programs Featuring the Heat Pump Rebate Program Customer Programs Director Kullmann presented an overview of RCEA's customer programs, detailing services across residential, commercial, public agency, and workforce education sectors. These 16 8/27/26
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programs are funded mostly through external sources such as California’s Regional Resilience Planning and Implementation Grant program and the Public Purpose Program (PPP), which is funded by a charge on all electricity bills. The Northern Rural Energy Network program and the Local Government Partnership are funded through the PPP. Historically, Humboldt County residents paid into the PPP but received little customer program service in return. RCEA staff bring these funds back to Humboldt County and rural Northern California in the form of energy efficiency customer programs. Residents do not need to be RCEA Community Choice Aggregation customers to participate in most of these programs.

Natural gas heating causes most of the greenhouse gas emissions from buildings in Humboldt County.

Director Kullmann explained the benefits of using electric heat pumps. Since 2025, RCEA issued 56 heat pump space heater rebates and 46 hot water heat pump rebates. RCEA will launch a new heat pump program that offers rebates as high as 100% for commercial customers and up to $7,000 for residential customers who work directly with contractors. RCEA will host an open house on September 15 to recruit local contractors.

The group discussed the costs and benefits of switching from natural gas to heat pumps. There might not be immediate cost savings due to high electric rates, but heat pumps offer long-term benefits including decarbonization and use as air conditioners during summer months. There were no public comments on this agenda item.

9.2 Introductory Study Session on Electricity Service Municipalization In response to Director requests for information on ways to reduce RCEA exposure to investor-owned utilities’ actions and to give RCEA more price control, Power Resources Director Engel and Regulatory and Legislative Manager Carlson presented an overview of public power options. Following two waves of municipal utility formation in the late 1800s as cities grew and electrification spread, and the early 2000’s after the Enron scandal, Community Choice Aggregators, municipal utilities, and rural electric co-operatives face challenges to formation and operation including investor-owned utility opposition, high asset transfer negotiation and infrastructure costs, and legal barriers that can take years to overcome. In the last 25 years, less than 10% of municipalization attempts in the U.S. succeeded.

Staff highlighted the success of CCAs in California, which currently meet nearly a quarter of the state's total electric load. Two other promising public power opportunities are greenfield development (electrification of areas formerly unserved by an investor-owned utility) and rural electric coops, which can borrow funds at low interest rates through the U.S. Department of Agriculture Rural Utilities Service.

Barriers to publicly-owned power infrastructure in Humboldt County include the region’s vast and difficult terrain, risk of assuming costs associated with wildfires, and lack of significant new industrial development as a potential electric revenue source.

The group discussed a local hybrid approach: municipal electricity for areas around Humboldt Bay and rural electric co-ops for more remote areas. Staff stressed the importance of legislative efforts to end the Power Charge Indifference Adjustment to gain more control over costs under the existing CCA framework. In the future, the Board will discuss revising RCEA’s Policy Platform to more strongly support publicly-owned power, continue work to sunset the PCIA, explore a regional approach to public power, and learn more about how rural electric cooperatives work. Staff asked the Board to prioritize issues to be addressed (cost savings, independence from investor-owned utility actions, or energy resilience) as different goals require different strategies.
17 8/27/26
RCEA Board of Directors DRAFT Minutes
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Community Advisory Committee member Carol Schmitt, speaking as a member of the public, highlighted the importance of considering energy resilience in future planning. Chair Gerace closed the public comment period.

10. Future Agenda Items
The Directors asked for updates on PCIA sunsetting efforts and a discussion on strategies to increase the regional electricity load.

Chair Gerace adjourned the meeting at 5:20 p.m.

Lori Taketa
Clerk of the Board
The author used Zoom AI to generate a draft of these minutes. After using this tool, the author reviewed, edited and takes full responsibility for the content of these minutes.
18

Staff Report
Agenda Item # 5.2
Information
Agenda Date September 24, 2026
To Board of Directors
Prepared by Lori Biondini, Business Planning and Finance Director Subject Profit & Loss, Balance Sheet and Monthly Disbursements Reports Summary
The attached Disbursements Report lists RCEA’s checks, debits, and electronic payments made during the period identified on the report. The Business Planning and Finance Director certifies that the disbursements were drawn in payment of demands conforming to RCEA’s adopted Financial Policy and budget.

The Financial Reports (Profit & Loss Budget vs. Actual and Balance Sheet) are presented to keep the Board apprised of current agency receipts and spending relative to budget line items.

Alignment with RCEA’s Strategic Plan
Agency financial tracking and reporting are necessary administrative functions supporting RCEA strategic plan goal implementation.

Financial Impact
The disbursements presented were drawn in payment of demands included within the adopted budget.

Staff Recommendation
Approve Disbursement Reports for July 2026, and Financial Reports for This Fiscal Year Through July 2026.

Attachments

1. Disbursements Report for July 1 through July 31, 2026

2. Profit & Loss Budget vs. Actual Report, July 2026

3. Balance Sheet as of July 31, 2026
19 This page
intentionally
left blank.
20 Accrual Basis Redwood Coast Energy Authority
Disbursements Report
As of July 31, 2026
Type Date Num Name Memo Amount
Liability Check 07/02/2026 ACH Ascensus 7/2/26 Payroll -14,574.55 Liability Check 07/02/2026 ACH EDD 7/2/26 Payroll -8,874.75 Liability Check 07/02/2026 ACH Internal Revenue Service 7/2/26 Payroll -38,292.90 Liability Check 07/02/2026 ACH Ascensus 7/2/26 Payroll -14,033.41 Liability Check 07/02/2026 ACH Colonial Life July 2026 Premiums -3,598.89 Bill Pmt -Check 07/02/2026 ACH CalCCA Operational Member Dues Qrtly FY 26/27 Q1 -33,948.00 Bill Pmt -Check 07/02/2026 ACH Choice Digital Corp NREN Program Residential Rebate- Client Fees May 2026 -63.60 Bill Pmt -Check 07/02/2026 ACH EDPR CA Solar Park LLC II May 2026-Contract Energy -1,089,266.14 Bill Pmt -Check 07/02/2026 ACH Sandrini BESS Storage LLC May 2026 Contract Energy Storage -1,183,824.15 Bill Pmt -Check 07/02/2026 ACH Viridity Energy Solutions, Inc. Tierra Buena RA-June 2026 -16,900.00 Bill Pmt -Check 07/02/2026 ACH Humboldt Made Emerald Level Community Impact Sponsorship Payment 2/2 -2,500.00 Bill Pmt -Check 07/02/2026 ACH County of Humboldt- Building Dept. Building permit for Orleans VFD -1,304.00 Bill Pmt -Check 07/02/2026 ACH County of Humboldt- Building Dept. Building permit for Orick CSD Addl Fees -212.00 Bill Pmt -Check 07/02/2026 WIRE Siteimprove, Inc. Implementation Plan & Software Fees -11,950.00 Check 07/02/2026 22567 NEM Customer Reissued: 2026 NEM Term Acct Closeout -277.27 Bill Pmt -Check 07/02/2026 22568 Advanced Security Systems Qrtly monitoring and service call -405.00 Bill Pmt -Check 07/02/2026 22569 Adventures Edge June e-bike vouchers -2,200.00 Bill Pmt -Check 07/02/2026 22570 Alber's Tractor and Ag Work June RCAM mowing service -2,150.00 Bill Pmt -Check 07/02/2026 22571 AM Conservation Group, Inc. NREN Res Kits-RCEA Qty 116 -12,599.71 Bill Pmt -Check 07/02/2026 22572 Amazon.com Monthly billing - May 2026 -4,484.04 Bill Pmt -Check 07/02/2026 22573 AT&T RCAM charges: 06/07-07/06/26 -333.95 Bill Pmt -Check 07/02/2026 22574 Busick, B. May 2026 Mileage Reimbursement -48.21 Bill Pmt -Check 07/02/2026 22575 Central Office Staff business cards x 3 -92.61 Bill Pmt -Check 07/02/2026 22576 Fortuna Chamber of Commerce 7/2026-7/2027 Membership Dues -400.00 Bill Pmt -Check 07/02/2026 22577 Humboldt Bay Coffee Co. Office coffee -108.50 Bill Pmt -Check 07/02/2026 22578 Humboldt HyCycle June e-bike vouchers -3,600.00 Bill Pmt -Check 07/02/2026 22579 Humboldt Transit Authority Staff bus passes Jan-Mar 2026 -256.00 Bill Pmt -Check 07/02/2026 22580 iPROMOTEu.com, Inc Community Strat event items -2,494.66 Bill Pmt -Check 07/02/2026 22581 McKinleyville Chamber of Commerce Event fees -2,500.00 Bill Pmt -Check 07/02/2026 22582 Mission Linen & Uniform Service Janitorial supplies and services -88.80 Bill Pmt -Check 07/02/2026 22583 NYLEX.net, Inc. Onsite network support services - July 2026 -4,909.00 Bill Pmt -Check 07/02/2026 22584 Pacific Paper Company Office supplies -37.64 Bill Pmt -Check 07/02/2026 22585 PG&E- EV 2931 Russell St EV station: 5/6/26-6/4/26 -372.02 Bill Pmt -Check 07/02/2026 22586 PG&E-Office Utility 5/14-6/11/26 utilities for 633 3rd Street -991.38 Bill Pmt -Check 07/02/2026 22587 PG&E - ACV RCAM site utilities 5/02/26- 6/01/26 -217.81 Bill Pmt -Check 07/02/2026 22588 PG&E CCA May 2026 CCE Charges -21,956.55 Bill Pmt -Check 07/02/2026 22589 Reider, S Mileage Reimbursement- June 2026 -71.27 Bill Pmt -Check 07/02/2026 22590 Revolution Bicycles, Inc. June e-bike vouchers -1,200.00 Bill Pmt -Check 07/02/2026 22591 Scrapper's Edge Banner for events -79.38 Bill Pmt -Check 07/02/2026 22592 Shred Aware Shredding services - June 2026 -68.95 Bill Pmt -Check 07/02/2026 22594 Taketa, L. May 2026 Purchase Reimbursement -23.47 Bill Pmt -Check 07/02/2026 22595 Times Printing Company Monthly move-in and late notices -1,766.74 Bill Pmt -Check 07/02/2026 22596 Times Printing Company Joint Rate Mailer Postcard w/Postage-qty 58,548 -30,840.90 Bill Pmt -Check 07/02/2026 22597 Verbeck, E. Travel Reimb- Diablo Canyon Tour -91.92 Bill Pmt -Check 07/02/2026 22598 Westside Community Improvement Assn. Venue Rental: 1/13/26 CAC mtg -187.50 Paycheck 07/02/2026 ACH Employees Payroll -94,820.02
Bill Pmt -Check 07/13/2026 ACH The Energy Authority Weekly CRR #CISO070826-JUN2026 -116,145.92 Bill Pmt -Check 07/14/2026 ACH Choice Digital Corp RCEA NEM Solar Cash Outs Commercial, Qty 60 -52,514.12 Bill Pmt -Check 07/15/2026 ACH The Energy Authority Monthly Services June 2026 -789,179.99 Liability Check 07/17/2026 ACH EDD 7/17/26 Paydate -8,885.46 Liability Check 07/17/2026 ACH Internal Revenue Service 7/17/26 Paydate -38,018.30

21 Accrual Basis Redwood Coast Energy Authority
Disbursements Report
As of July 31, 2026
Type Date Num Name Memo Amount
Liability Check 07/17/2026 ACH Ascensus 7/17/26 Paydate -14,602.61 Liability Check 07/17/2026 ACH Ascensus 7/17/26 Paydate -14,045.44 Bill Pmt -Check 07/17/2026 ACH CalPine Corporation June 2026 Services -70,565.20 Bill Pmt -Check 07/17/2026 ACH Humboldt Sawmill Co. June 2026 Electricity Charge -625,857.70 Bill Pmt -Check 07/17/2026 ACH Leapfrog Power, Inc June 2026 RA Invoice -37,180.00 Bill Pmt -Check 07/17/2026 ACH Mendocino Council of Governments NREN Implemetation Task Orders Q3 2026 -188,399.83 Bill Pmt -Check 07/17/2026 ACH Sonoma Clean Power Authority June 2026 - Flex RA -261,000.00 Bill Pmt -Check 07/17/2026 ACH SMUD NREN Res Sector needs assesment- May 2026 -68,265.00 Bill Pmt -Check 07/17/2026 WIRE Foster Clean Power A, LLC June 2026 Contract Energy -39,153.61 Bill Pmt -Check 07/17/2026 WIRE Foster Clean Power B, LLC June 2026 Contract Energy -44,754.49 Check 07/17/2026 22599 NEM Customer 2026 NEM Term Account Closeout-Reissued -593.19 Check 07/17/2026 22600 NEM Customer 2026 NEM Closeout-Reissued -80.38 Check 07/17/2026 22601-22 NEM Customers 2026 NEM Closeout -754.86 Bill Pmt -Check 07/17/2026 22623 Adventures Edge July 2026: 1 E-Bike Voucher -600.00 Bill Pmt -Check 07/17/2026 22624 Arcata Technology Center Site Host Reimbursement 04/01/26-06/30/26 -315.92 Bill Pmt -Check 07/17/2026 22625 AT&T RCAM Router charges 05/19-06/18/26 -163.00 Bill Pmt -Check 07/17/2026 22626 AT&T RCAM data charges 6/29/26-7/28/26 -665.37 Bill Pmt -Check 07/17/2026 22627 Atkins Drafting 718 & 720 3rd: 3D Scan and DWG as-builts -4,364.25 Bill Pmt -Check 07/17/2026 22628 Bishop, M. June 2026 Reimbursements -257.45 Bill Pmt -Check 07/17/2026 22629 Black Humboldt Juneteenth 2026 Event Sponsorship -500.00 Bill Pmt -Check 07/17/2026 22630 Blue Lake Rancheria Site Host Reimbursement 04/01/26-06/30/26 -1,248.10 Bill Pmt -Check 07/17/2026 22631 Busick, B. July 2026 Mileage Reimbursement -70.18 Bill Pmt -Check 07/17/2026 22632 Chargepoint Qty 8, Com. cloud plans for Arcata Com center -2,960.00 Bill Pmt -Check 07/17/2026 22633 City of Arcata May 2026 Utility User Tax -5,576.17 Bill Pmt -Check 07/17/2026 22634 City of Arcata May 2026 Excessive Electricity Use Tax -383.62 Bill Pmt -Check 07/17/2026 22635 City of Arcata Site Host Reimbursement 04/01/26-06/30/26 -1,352.08 Bill Pmt -Check 07/17/2026 22636 City of Blue Lake Site Host Reimbursement 04/01/26-06/30/26 -376.32 Bill Pmt -Check 07/17/2026 22637 City of Blue Lake Building permit for Blue Lake VFD -1,030.00 Bill Pmt -Check 07/17/2026 22638 City of Eureka-Water 917 & 633 3rd. St. 05/25/26-06/25/26 -389.64 Bill Pmt -Check 07/17/2026 22639 City of Eureka - REVNet Site Host Reimbursement 04/01/26-06/30/26 -628.21 Bill Pmt -Check 07/17/2026 22640 City of Trinidad Site Host Reimbursement 04/01/26-06/30/26 -483.62 Bill Pmt -Check 07/17/2026 22641 County of Ventura Civicwell 3C-REN/NREN 2026 -133,938.57 Bill Pmt -Check 07/17/2026 22642 CPH Sponsored Programs Foundation Apr-May 2026 RCAM services -13,388.00 Bill Pmt -Check 07/17/2026 22643 Donald Dame CCE Consulting services- June 2026 -218.75 Bill Pmt -Check 07/17/2026 22644 Engel, R. June 2026 Mileage Reimb. -39.88 Bill Pmt -Check 07/17/2026 22645 Frontier Energy, Inc. May 2026 NREN services -54,658.50 Bill Pmt -Check 07/17/2026 22646 Humboldt Bay Coffee Co. Office Coffee- 633 3rd St. -64.10 Bill Pmt -Check 07/17/2026 22647 Humboldt Transit Authority Staff bus passes Apr-June 2026 -230.00 Bill Pmt -Check 07/17/2026 22648 HWMA June 2026 Dump Fees-633 3rd Attic Cleanout -227.25 Bill Pmt -Check 07/17/2026 22649 Kilowatt Engineering, Inc. May & June 2026 services -22,257.50 Bill Pmt -Check 07/17/2026 22650 KnowBe4 Training Subscription 07/22/2026-07/21/2029 -3,661.32 Bill Pmt -Check 07/17/2026 22651 Law Offices of Nancy Diamond June 2026 services -4,928.00 Bill Pmt -Check 07/17/2026 22652 Law Offices of Susie Berlin May & June 2026 services -7,862.50 Bill Pmt -Check 07/17/2026 22653 Marc Malfatti Electric EV Charging Station electrical work: DMV site -25,650.00 Bill Pmt -Check 07/17/2026 22654 Martin, Kelsey CCEC Conference Reimb 6/23-6/26/26 -344.39 Bill Pmt -Check 07/17/2026 22655 Mission Linen & Uniform Service June 2026 services and supplies -140.77 Bill Pmt -Check 07/17/2026 22656 North Coast Unified Air Quality Site Host Reimbursement 04/01/26-06/30/26 -629.04 Bill Pmt -Check 07/17/2026 22657 Open Door Community Health Center Site Host Reimbursement 04/01/26-06/30/26 -325.27 Bill Pmt -Check 07/17/2026 22658 Pacific Paper Company Office supplies -55.11 Bill Pmt -Check 07/17/2026 22659 PG&E- EV Utilities for 3 EV accounts -1,960.78 Bill Pmt -Check 07/17/2026 22660 PG&E-Office Utility Utilities for 2 accounts -388.40

22 Accrual Basis Redwood Coast Energy Authority
Disbursements Report
As of July 31, 2026
Type Date Num Name Memo Amount
Bill Pmt -Check 07/17/2026 22661 Rodriguez, Louis Mileage reimbursement - June 2026 -99.76 Bill Pmt -Check 07/17/2026 22662 Scrapper's Edge July 2026 purchases -65.66 Bill Pmt -Check 07/17/2026 22663 Shred Aware Shredding services - 633 Attic Clean-out boxes -1,037.78 Bill Pmt -Check 07/17/2026 22664 St. Joseph Hospital, Eureka Site Host Reimbursement 04/01/26-06/30/26 -2,265.93 Bill Pmt -Check 07/17/2026 22665 Taketa, L. June 2026 reimbursements -390.00 Bill Pmt -Check 07/17/2026 22666 Special District Risk Managment P&L VOID: Not received by vendor as of 8/31/26, reissued as ACH 0.00 Paycheck 07/17/2026 ACH Employees Payroll -93,051.62
Check 07/20/2026 ACH VISA- Commercial Card Payment for Statement Date 6/30/26 -20,342.27 Check 07/21/2026 Debit Columbia Bank Service Charge -357.99 Check 07/21/2026 Debit Columbia Bank Service Charge -274.65 Bill Pmt -Check 07/21/2026 ACH Choice Digital Corp NREN Program Residential Rebate Prefunding -40,000.00 Bill Pmt -Check 07/21/2026 ACH Snow Mountain Hydro, LLC June 2026 Electricity -2,263.08 Bill Pmt -Check 07/30/2026 ACH EDPR CA Solar Park LLC II June 2026-Contract Energy -1,004,340.66 Liability Check 07/31/2026 ACH Ascensus 7/31/26 Paydate -16,772.81 Liability Check 07/31/2026 ACH CICCS Coalition for Controlling Insurance July 2026 Premiums -68.68 Liability Check 07/31/2026 ACH Colonial Life August 2026 Premiums -3,628.57 Liability Check 07/31/2026 ACH EDD 7/31/26 Paydate -9,148.10 Liability Check 07/31/2026 ACH Internal Revenue Service 7/31/26 Paydate -38,951.88 Liability Check 07/31/2026 ACH Keenan August 2026 Premiums -52,977.48 Liability Check 07/31/2026 ACH Principal Life Insurance Company August 2026 Premiums -133.74 Liability Check 07/31/2026 ACH Ascensus 7/31/26 Paydate -14,315.46 Bill Pmt -Check 07/31/2026 ACH CA Dept. of Tax & Fee Administration Electrical Energy Surcharge Return Q2 2026 -36,556.00 Bill Pmt -Check 07/31/2026 ACH John Winzler Office Lease - 633 3rd St. Aug 2026 -8,144.97 Bill Pmt -Check 07/31/2026 ACH Sandrini BESS Storage LLC June 2026 Contract Energy Storage -1,217,014.50 Bill Pmt -Check 07/31/2026 ACH SMUD NREN Res Sector needs assesment- June 2026 -56,365.00 Bill Pmt -Check 07/31/2026 ACH Viridity Energy Solutions, Inc. Tierra Buena RA-July 2026 -16,900.00 Bill Pmt -Check 07/31/2026 WIRE PG&E Voluntary Allocation Mar 2026 Forecast Price- VA -83,558.10 Liability Check 07/31/2026 22667 Ameritas Life Insurance Corp.- Vision August 2026 Premiums -524.04 Liability Check 07/31/2026 22668 Ameritas Life Insurance Corp. - Dental August 2026 Premiums -3,160.64 Bill Pmt -Check 07/31/2026 22669 Adventures Edge July 2026 e-bike vochers -1,600.00 Bill Pmt -Check 07/31/2026 22670 AM Conservation Group, Inc. July 2026 kits -27,494.49 Bill Pmt -Check 07/31/2026 22671 Ascensus 03/01-05/31/26 Recordkeeping Fee -1,105.25 Bill Pmt -Check 07/31/2026 22672 AT&T RCAM charges: 07/07-08/06/26 -333.95 Bill Pmt -Check 07/31/2026 22673 Atkins Drafting 718 & 720 3rd: Prelim Floor Plan Design & Consult -2,080.00 Bill Pmt -Check 07/31/2026 22674 Baker, Henry CCEC Conference: Reimb 6/23-6/26/26 -307.99 Bill Pmt -Check 07/31/2026 22675 Bishop, M. Purchase reimbursement - Recology E-waste disposal -20.00 Bill Pmt -Check 07/31/2026 22676 Bohn, Juliette Reimb in-person NREN Mtg 6/29-6/30-26 -64.93 Bill Pmt -Check 07/31/2026 22677 Braun Blaising & Wynne, P.C. Regulatory & Procurement legal services May 2026 -2,815.99 Bill Pmt -Check 07/31/2026 22678 Burks, E. CCEC Conference: Per Diem & Reimb 6/23-6/26/26 -365.24 Bill Pmt -Check 07/31/2026 22679 Carter Properties 917 3rd Street Office Lease - Aug 2026 rent -2,450.00 Bill Pmt -Check 07/31/2026 22680 CPH Sponsored Programs Foundation June 2026 RCAM services -3,020.00 Bill Pmt -Check 07/31/2026 22681 Department of Justice Customer 165251, Fingerprinting Fee -49.00 Bill Pmt -Check 07/31/2026 22682 Developed Employment Services, LLC. 633 3rd St. Yard work -106.45 Bill Pmt -Check 07/31/2026 22683 Donnelly, S. CCEC Conference: Reimb 6/23-6/26/26 -86.92 Bill Pmt -Check 07/31/2026 22684 EAN Services, LLC Staff travel vehicle rentals June 2026 -153.66 Bill Pmt -Check 07/31/2026 22685 Eureka Humboldt Fire Extinguisher Co. Inc July 2026 office inspection -239.90 Bill Pmt -Check 07/31/2026 22686 Ferndale Chamber of Commerce FY 26/27 Annual Membership -50.00 Bill Pmt -Check 07/31/2026 22687 Friends of the Lost Coast 2026 Natural Science Day Event Sponsorship -500.00 Bill Pmt -Check 07/31/2026 22688 Frontier Energy, Inc. June 2026 NREN services -55,300.73 Bill Pmt -Check 07/31/2026 22689 Heidi Moore-Guynup CCEC Conference: Board Member travel reimb -866.90 Bill Pmt -Check 07/31/2026 22690 Hooven & Reese, Inc. Redway & Garberville EV project -6,509.90

23 Accrual Basis Redwood Coast Energy Authority
Disbursements Report
As of July 31, 2026
Type Date Num Name Memo Amount
Bill Pmt -Check 07/31/2026 22691 Humboldt County DHHS 26/27 Annual HazMat Fees Record: EH22-00046 -629.39 Bill Pmt -Check 07/31/2026 22692 Intellistack Annual Software Charge 4/25/26-4/24/27 -7,451.51 Bill Pmt -Check 07/31/2026 22693 John Winzler VOID: Ck 22693 and set up as ACH payment 0.00 Bill Pmt -Check 07/31/2026 22694 Kullmann, S. CCEC Conference Reimb. 6/22-6/26/26 -560.62 Bill Pmt -Check 07/31/2026 22695 Mattio, B. CCEC Conference Reimb. 6/22-6/26/26 -789.15 Bill Pmt -Check 07/31/2026 22696 Means, M. June & July travel reimbursements -293.43 Bill Pmt -Check 07/31/2026 22697 Mission Linen & Uniform Service July 2026 services -140.77 Bill Pmt -Check 07/31/2026 22698 Mobley Construction Inc. Install of EV charger- Orleans - rem. 25% -24,288.25 Bill Pmt -Check 07/31/2026 22699 Newport Group Participant Fees for Retirement Plan -7/1-9/30/26 -1,044.59 Bill Pmt -Check 07/31/2026 22700 North Coast Cleaning Services, Inc. June 2026 services -1,090.00 Bill Pmt -Check 07/31/2026 22701 Optimum Business-633 633 3rd St: Phone & Internet- 07/01-07/31/26 -1,103.78 Bill Pmt -Check 07/31/2026 22702 PG&E- EV Payment for 4 accounts -914.90 Bill Pmt -Check 07/31/2026 22703 PG&E-Office Utility 6/12-7/13/26 utilities for 633 3rd Street -1,084.51 Bill Pmt -Check 07/31/2026 22704 PG&E - ACV RCAM site utilities 6/02/26- 7/01/26 -269.91 Bill Pmt -Check 07/31/2026 22705 PG&E CCA June 2026 CCE Charges -21,959.77 Bill Pmt -Check 07/31/2026 22706 Reider, S Mileage Reimbursement- July 2026 -20.45 Bill Pmt -Check 07/31/2026 22707 Revolution Bicycles, Inc. July 2026: 1 E-Bike Voucher -400.00 Bill Pmt -Check 07/31/2026 22708 Rodriguez, Louis Mileage reimbursement - July 2026 -58.80 Bill Pmt -Check 07/31/2026 22709 Shred Aware Shredding services - e-waste -410.00 Bill Pmt -Check 07/31/2026 22710 Terry, P. CCEC Conference Reimb. 6/22-6/26/26 -846.00 Bill Pmt -Check 07/31/2026 22711 Times Printing Company Late notice envelopes -296.24 Bill Pmt -Check 07/31/2026 22712 Ubeo Business Services 633+ 917 3rd St Printer Charges: 6/6-7/5/26 -263.14 Bill Pmt -Check 07/31/2026 22713 WREGIS Qty 60,000 Transferred & 53 Retired RECS -240.21 Bill Pmt -Check 07/31/2026 22714 Amazon.com Monthly billing - June 2026 -1,112.21 Paycheck 07/31/2026 ACH Employees Payroll -96,205.91
TOTAL -8,261,048.06

24 Redwood Coast Energy Authority
Profit & Loss Budget vs. Actual
July 2026
Jul 26 Budget % of Budget
Ordinary Income/Expense
Income
Total 4 GRANTS AND DONATIONS 20,865.17
5 REVENUE EARNED
Total 5000 · Revenue - government agencies 2,518,068.25 17,548,342.00 14.35% Total 5100 · Revenue - program related 8,884.93 152,404.00 5.83% Total 5300 · Revenue - Interest Earned 104,479.26 600,000.00 17.41% Total 5400 · Revenue-nongovernment agencies 38,646.25 515,532.00 7.5% Total 5500 · Revenue - Electricity Sales 3,705,347.61 51,359,098.00 7.22% Total 5 REVENUE EARNED 6,375,426.30 70,175,376.00 9.09% Total Income 6,396,291.47 70,175,376.00 9.12%
Gross Profit 6,396,291.47 70,175,376.00 9.12%
Expense
Total 6 WHOLESALE POWER SUPPLY 4,289,412.22 53,053,147.00 8.09% Total 7 PERSONNEL EXPENSES 419,895.41 6,848,843.00 6.13% Total 8.1 FACILITIES AND OPERATIONS 331,694.99 1,412,926.00 23.48% Total 8.2 COMMUNICATIONS AND OUTREACH 6,740.16 383,463.00 1.76%

8.4 PROFESSIONAL & PROGRAM SRVS
8400 · Regulatory 34,755.50 400,101.00 8.69%
Total 8410 · Contracts - Program Related Ser 484,017.17 9,067,655.00 5.34% 8419 · Organization Dues & Memberships 0.00 468,839.00 0.0% 8420 · Accounting 3,150.00 123,000.00 2.56%
8430 · Legal 12,225.22 211,500.00 5.78%
8450 · Wholesale Services - TEA 102,274.73 1,146,894.00 8.92% 8470 · Data Management - Calpine 77,455.30 774,452.00 10.0% 8480 · Customer Billing - PG&E 21,932.54 254,994.00 8.6% Total 8.4 PROFESSIONAL & PROGRAM SRVS 735,810.46 12,447,435.00 5.91% Total 8.6 INCENTIVES & REBATES 82,350.69 4,454,047.00 1.85% Total 9 NON OPERATING COSTS 632.64 129,300.00 0.49%
Total Expense 5,866,536.57 78,729,161.00 7.45%
Net Ordinary Income 529,754.90 -8,553,785.00 -6.19%
Net Income 529,754.90 -8,553,785.00 -6.19%

25 Redwood Coast Energy Authority
Balance Sheet
As of July 31, 2026
Jul 31, 26
ASSETS
Current Assets
Checking/Savings
1010 · Petty Cash 300.00
1060 · Umpqua Checking Acct 0560 172,395.43
1071 · Umpqua Deposit Cntrol Acct 8215 522,210.15
1075 · Umpqua Reserve Account 2300 22,286,639.53
1077 · JP Morgan Chase Act 74999 386,207.84
1078 · CA CLASS Reserve Fund 0001 13,526,032.70
Total Checking/Savings 36,893,785.65
Total Accounts Receivable 2,641,414.48
Other Current Assets
1101 · Allowance for Doubtful Accounts -6,974,626.06
1103 · Electricity Receivable 13,872,142.07
1120 · Inventory Asset 19,835.15
1205 · Prepaid Insurance 21,993.56
1210 · Retentions Receivable 113,433.87
Total Other Current Assets 7,052,778.59
Total Current Assets 46,587,978.72
Total Fixed Assets 13,897,630.29
Other Assets
1700 · Security Deposits 795,663.42
1800 · Deferred Outflow of Resources 196,000.00
Total Other Assets 991,663.42
TOTAL ASSETS 61,477,272.43

LIABILITIES & EQUITY
Liabilities
Current Liabilities
Total Accounts Payable 4,693,470.40
Total Credit Cards 13,535.79
Other Current Liabilities
2002 · Deposits Refundable 1,573,470.01
2011 · NEM Escrow Liability 271,124.38
2013 · Unearned Revenue 7,075,981.22
Total 2100 · Payroll Liabilities 257,538.94
Total 2200 · Accrued Expenses 13,162.61
Total Other Current Liabilities 9,191,277.16
Total Current Liabilities 13,898,283.35
Total Long Term Liabilities 5,585,364.54
Total Liabilities 19,483,647.89
Equity
3900 · Fund Balance 41,463,869.64
Net Income 529,754.90
Total Equity 41,993,624.54
TOTAL LIABILITIES & EQUITY 61,477,272.43

26

Staff Report
Agenda Item # 7.1
Information
Agenda Date September 24, 2026
To Board of Directors
Prepared by Forrest Novotny, Power Resources Compliance Technician Subject 2025 Power Source Disclosure Attestation
Summary
Staff ask that the Board adopt a resolution formally approving and attesting to the information in the 2025 Power Source Disclosure Report as part of the documentation required by the California Energy Commission (CEC) for compliance with the Disclosure Program.

RCEA’s 2025 REpower power mix was 50% renewable, and 50% carbon-free. Large hydro made up 42% of the portfolio, and the Diablo Canyon nuclear allocation served 8% of RCEA's load. In comparison, RCEA’s 2024 REpower power mix was 46% renewable, 13% carbon-free large hydro, and 41% unspecified sources. Both the renewable and carbon free percentages were greater in 2025 than in 2024 and included no unspecified sources. RCEA was able to increase the renewable attribute because 2025 was Sandrini Solar's first full year of generation, and because the Foster Avenue A and B projects came online later in the year. RCEA sold off excess renewable energy from its portfolio for 2025 to address short-term financial challenges but still was able to increase overall renewable procurement relative to prior years. Some short-term carbon free large hydro was procured to meet RCEA's overall target of 100% renewable or carbon free resources for 2025.

Because Sandrini Solar, Foster A and B and North Coast Highway Solar 1 and 2 are now fully online, combined with the PG&E carbon-free nuclear allocation and the remainder of RCEA's existing contracts, staff project that RCEA will meet the Board-adopted goal of 62% renewable and 38% carbon free with no unspecified power for 2026. This means that in 2026 RCEA will continue meeting its RePower Strategic Plan goal: 100% of RCEA’s power mix comprised of state-designated renewable energy sources and state-designated net-zero-carbon-emissions sources.

RCEA’s 2025 REpower+ 100% renewable power mix consisted of 40% solar, 20% wind, and 40% small hydro power.

The state’s power mix included 45% renewables in 2024. The state’s 2025 power mix is still being calculated.
27

Background
Each year, staff present RCEA’s power mix from the previous year to the Board. This power mix is submitted to the CEC as part of the Power Source Disclosure Program. Staff submitted the 2025 Power Source Disclosure Report (Exhibit A to the accompanying Board Resolution 2026-10) to the CEC by the due date. The report shows RCEA’s annual energy purchases from each generating facility from last year, and percentages of each resource type in the REpower and REpower+ products. Additionally, the Power Source Disclosure includes the greenhouse gas emissions intensity of each product.

Later this year, staff will mail out the 2025 Power Content Label to all current RCEA customers. The Power Content Label includes information from the Power Source Disclosure Report and compares RCEA’s power content and greenhouse gas emissions to the state’s overall mix and emissions. The CEC is delayed in issuing the Power Content Label template this year and will be creating the Label on behalf of each load-serving entity instead. RCEA expects to receive the Power Content Label in mid-September and send the mailers out in the fourth quarter of 2026.

Equity Impacts
Not Applicable, this is a compliance requirement.

Alignment with RCEA’s Strategic Plan
Not Applicable, this is a compliance requirement.

Financial Impact
The RePower Strategic Plan procurement goal will be achieved within budgets set by this Board despite temporary reductions in renewable energy procurement in the previous two years due to financial constraints.

In June 2024, the Board voted to reduce the RePower renewable energy procurement goal to the State’s renewable energy procurement targets for the 2024 and 2025 calendar years. At that time, depleted reserves were projected if RCEA continued to pursue the RePower Strategic Plan’s more aggressive renewable purchasing goals amid rising resource adequacy and renewable energy prices. By February 2025, agency revenue exceeded prior projections. The Board adjusted the agency budget accordingly and decided not to sell renewable energy products in excess of the state standards. The decision was projected to be cost neutral and resulted in renewable energy procurement that exceeded the State’s standard renewable procurement goal. For fiscal year 2026-2027, the board elected to stand firm on renewable and carbon-free goals, therefore RCEA expects to meet the portfolio requirement of 62% renewable and 38% carbon-free for reporting year 2026.

Staff Recommendation
Adopt Resolution 2026-10 Approving and Attesting to the Veracity of RCEA’s 2025 Power Source Disclosure Report.
28

Attachments
• Resolution No. 2026-10 Approving and Attesting to the Veracity of RCEA’s 2025 Power Source Disclosure Report.
• Exhibit A: RCEA 2025 Power Source Disclosure Report
29

RESOLUTION NO. 2026-10

A RESOLUTION OF THE BOARD OF DIRECTORS

OF THE REDWOOD COAST ENERGY AUTHORITY

APPROVING AND ATTESTING TO THE VERACITY
OF THE 2025 POWER SOURCE DISCLOSURE REPORT
WHEREAS, Senate Bill 1305 was adopted in 1997, establishing an Electricity Generation Source Disclosure (also known as Power Source Disclosure or “PSD”) Program, which requires retail suppliers of electricity to annually submit a PSD Report to the California Energy Commission (“CEC”) and to annually mail a Power Content Label (“PCL”) to their electricity customers; and WHEREAS, Redwood Coast Energy Authority (“RCEA”) is a retail supplier of electricity as defined by the PSD Program (Ca. Code of Regs., Title 20, Section 1391(r)); and WHEREAS, the PSD Regulation requiring an annual audit by an outside certified public accountant of the information in the annual PSD Report, was updated effective May 4, 2020, with an exemption from this requirement for retail suppliers that are public agencies providing electric services, provided that the governing body of the public agency approves at a public meeting the submission to the CEC of an attestation of the veracity of the annual report for each electricity product; and WHEREAS, RCEA is a public agency providing electric services; and WHEREAS, the CEC exemption therefore allows the RCEA Board of Directors to approve an attestation of the veracity of RCEA’s 2025 PSD Annual Report provided hereto as Exhibit A.

NOW, THEREFORE, the Board of Directors of the Redwood Coast Energy Authority resolves as follows:

1. The 2025 Power Source Disclosure Report provided as Exhibit A is hereby approved; and

2. The Board of Directors hereby attests to the veracity of the information presented in the 2025 Power Source Disclosure Report.

Adopted this 24th day of September 2026.

ATTEST:

Michael Gerace, RCEA Board Chair Lori Taketa, Clerk of the Board Date: _________________________ Date: ________________________ 30

CLERK'S CERTIFICATE
I hereby certify that the foregoing is a true and correct copy of Resolution No. 2026 - 10 passed and adopted at a regular meeting of the Redwood Coast Energy Authority, County of Humboldt, State of California, held on the 24th day of September 2026, by the following vote:

AYES:

NOES:

ABSENT:

ABSTENTIONS:

Clerk of the Board, Redwood Coast Energy Authority
31

Exhibit A: RCEA 2025 Power Source Disclosure Report
32 Resource and GHG Allocations
*indicates GHG figures are preliminary until the calculation of the annual unspecified power emissions factor Power Sources and Emissions REpower REpower+
Electricity Portfolio
Name 3
Electricity Portfolio
Name 4
Electricity Portfolio
Name 5
Electricity Portfolio
Name 6 Other End Uses Losses
Retail Sales, Other End Uses, Losses (MWh) 500,734 14,705 - - - - - 25,457 Total Net Specified (MWh) 500,734 14,705 - - - - - 25,457 Biomass & Biogas 31,280 - - - - - - - Geothermal 206 - - - - - - - Eligible Hydroelectric 12,066 5,818 - - - - - - Solar 209,062 5,819 - - - - - 870 Wind - 3,068 - - - - - - Large Hydroelectric 210,375 - - - - - - 24,587 Nuclear 37,745 - - - - - - - Emerging Technologies - - - - - - - - Other - - - - - - - - Natural Gas - - - - - - - - Coal & Petroleum - - - - - - - - Unspecified Power - ACS - - - - - - - - Unspecified Power - Direct Import - - - - - - - - Unspecified Power - Spot Market - - - - - - - - Unspecified Power - Total - - - - - - - - Unspecified GHGs (MT CO 2e)* - - - - - - - - Specified GHGs (MT CO2e) 1,738 - - - - - - -
Total GHGs (MT CO2e)* 1,738 - - - - - - - Checks Status GHG Emissions Intensity (MT CO2e/MWh)* 0.003 - #DIV/0! #DIV/0! #DIV/0! #DIV/0! - - Portfolio and other end use allocations

COMPLETE
PCL Emissions Intensity (lbs CO2e/MWh)*
8 0 #DIV/0! #DIV/0! #DIV/0! #DIV/0!
--
Specified resources allocated

COMPLETE
Retail Sales, Other End Uses,
Specified Losses 500,734 14,705 25,457 Coal allocated COMPLETE Unmet Load (MWh) - - - - - - - -
Oversupply not negative COMPLETE PCL GHG Allocations (MT CO2e) Oversupply Facility Name Fuel Type State or Province WREGIS ID of REC Source RPS ID of REC Source EIA ID of Delivered Energy Loss Factor Gross MWhs Procured Specified Resales MWhs Net MWhs Procured Firmed & Shaped Resource? Eligible for Firmed & Shaped Grandfathering? Specified Losses Covered by Seller? Total EF (MT CO2e/MWh) Total GHGs PCL EF (MT CO2e/MWh) REpower REpower+ Electricity Portfolio Name 3 Electricity Portfolio Name 4 Electricity Portfolio Name 5 Electricity Portfolio Name 6 Other End Uses Specified Procurement Covering Losses Total Specified Losses Remainder/Oversupply Facility Name REpower REpower+ Electricity Portfolio Name 3 Electricity Portfolio Name 4 Electricity Portfolio Name 5 Electricity Portfolio Name 6 Other End Uses PCL GHGs Specified Procurement Covering Losses PCL GHGs Facility Name Fuel Type Net Procurement Oversupply Losses Annual PCL GHGs (MT CO2e) A. G. Wishon Powerhouse - A. G. Wishon Powerhouse Eligible Hydroelectric CA W344 60032 293 0.044 10 10 0.0000 - 0.0000 10 - - A. G. Wishon Powerhouse - A. G. Wishon Powerhouse - - - - - - - - - - - - - Agua Caliente Solar - Block 1 Solar AZ W2427 60894 57373 0.066 53 53 0.0000 - 0.0000 53 - 3 Agua Caliente Solar - Block 1 - - - - - - - - - - - - - Agua Caliente Solar - Block 10 Solar AZ W3621 60894 57373 0.066 49 49 0.0000 - 0.0000 49 - 3 Agua Caliente Solar - Block 10 - - - - - - - - - - - - - Agua Caliente Solar - Block 11 Solar AZ W3829 60894 57373 0.066 49 49 0.0000 0.000 - 0 49 - 3 Agua Caliente Solar - Block 11 - - - - - - - - - - - - - Agua Caliente Solar - Block 12 Solar AZ W3953 60894 57373 0.066 22 22 0.0000 0.000 - 0 22 - 1 Agua Caliente Solar - Block 12 - - - - - - - - - - - - -Agua Caliente Solar - Block 2 Solar AZ W2576 60894 57373 0.066 53 53 0.0000 - 0.0000 53 - 3 Agua Caliente Solar - Block 2 - - - - - - - - - - - - - Agua Caliente Solar - Block 3 Solar AZ W2668 60894 57373 0.066 53 53 0.0000 0.000 - 0 53 - 3 Agua Caliente Solar - Block 3 - - - - - - - - - - - - - Agua Caliente Solar - Block 4 Solar AZ W2782 60894 57373 0.066 38 38 0.0000 - 0.0000 38 - 3 Agua Caliente Solar - Block 4 - - - - - - - - - - - - - Agua Caliente Solar - Block 5 Solar AZ W2838 60894 57373 0.066 54 54 0.0000 - 0.0000 54 - 4 Agua Caliente Solar - Block 5 - - - - - - - - - - - - - Agua Caliente Solar - Block 6 Solar AZ W2844 60894 57373 0.066 54 54 0.0000 - 0.0000 54 - 4 Agua Caliente Solar - Block 6 - - - - - - - - - - - - - Agua Caliente Solar - Block 7 Solar AZ W2925 60894 57373 0.066 54 54 0.0000 - 0.0000 54 - 4 Agua Caliente Solar - Block 7 - - - - - - - - - - - - - Agua Caliente Solar - Block 8 Solar AZ W3240 60894 57373 0.066 49 49 0.0000 - 0.0000 49 - 3 Agua Caliente Solar - Block 8 - - - - - - - - - - - - - Agua Caliente Solar - Block 9 Solar AZ W2812 60894 57373 0.066 45 45 0.0000 - 0.0000 45 - 3 Agua Caliente Solar - Block 9 - - - - - - - - - - - - - Alamo Solar - Alamo Solar Solar CA W4546 61453 59469 0.044 77 77 0.0000 - 0.0000 77 - 3 Alamo Solar - Alamo Solar - - - - - - - - - - - - - Alta Powerhouse - Alta Powerhouse Eligible Hydroelectric CA W335 60033 214 0.044 3 3 0.0000 - 0.0000 3 - - Alta Powerhouse - Alta Powerhouse - - - - - - - - - - - - - Antelope West Solar - Antelope West Solar Solar CA W4322 61850 58626 0.044 68 68 0.0000 - 0.0000 68 - 3 Antelope West Solar - Antelope West Solar - - - - - - - - - - - - - Atwell Island - Atwell Island PV Solar Generating Facility Solar CA W3159 60947 58366 0.044 44 44 0.0000 - 0.0000 44 - 2 Atwell Island - Atwell Island PV Solar Generating Facility - - - - - - - - - - - - - AV Solar Ranch 1, LLC - Antelope Solar Ranch - Block 7 Solar CA W3474 60790 57378 0.044 93 93 0.0000 - 0.0000 93 4 - AV Solar Ranch 1, LLC - Antelope Solar Ranch - Block 7 - - - - - - - - - - - - - AV Solar Ranch 1, LLC - AVSR1 - Antelope Solar Ranch - Solar CA W4141 60790 57378 0.044 151 151 0.0000 - 0.0000 151 7 - AV Solar Ranch 1, LLC - AVSR1 - Antelope Solar Ranch - Block 1 & 2 - - - - - - - - - - - - -AV Solar Ranch 1, LLC - AVSR1 - Antelope Solar Ranch - Solar CA W2803 60790 57378 0.044 78 78 0.0000 - 0.0000 78 3 - AV Solar Ranch 1, LLC - AVSR1 - Antelope Solar Ranch - Block 3 - - - - - - - - - - - - -AV Solar Ranch 1, LLC - AVSR1 - Antelope Solar Ranch - Solar CA W3274 60790 57378 0.044 101 101 0.0000 - 0.0000 101 4 - AV Solar Ranch 1, LLC - AVSR1 - Antelope Solar Ranch - Block 4 - - - - - - - - - - - - -AV Solar Ranch 1, LLC - AVSR1 - Antelope Solar Ranch - Solar CA W3275 60790 57378 0.044 64 64 0.0000 - 0.0000 64 3 - AV Solar Ranch 1, LLC - AVSR1 - Antelope Solar Ranch - Block 5 - - - - - - - - - - - - -AV Solar Ranch 1, LLC - AVSR1 - Antelope Solar Ranch - Solar CA W3280 60790 57378 0.044 52 52 0.0000 - 0.0000 52 2 - AV Solar Ranch 1, LLC - AVSR1 - Antelope Solar Ranch - Block 6 - - - - - - - - - - - - -AV Solar Ranch 1, LLC - AVSR1 - Antelope Solar Ranch - Solar CA W3849 60790 57378 0.044 169 169 0.0000 - 0.0000 169 7 - AV Solar Ranch 1, LLC - AVSR1 - Antelope Solar Ranch - Block 8 & 9 - - - - - - - - - - - - - Bakersfield Solar - SKIC 20 Solar CA W4550 61558 61117 0.044 61 61 0.0000 - 0.0000 61 3 - Bakersfield Solar - SKIC 20 - - - - - - - - - - - - - Bayshore Solar A - Big Sky Solar 6 Solar CA W5731 63133 60481 0.044 72 72 0.0000 - 0.0000 72 3 - Bayshore Solar A - Big Sky Solar 6 - - - - - - - - - - - - - Bayshore Solar B - Big Sky Solar 7 Solar CA W5737 63134 60474 0.044 68 68 0.0000 - 0.0000 68 3 - Bayshore Solar B - Big Sky Solar 7 - - - - - - - - - - - - - Bayshore Solar C - Big Sky Solar 8 Solar CA W5738 63135 60475 0.044 66 66 0.0000 - 0.0000 66 3 - Bayshore Solar C - Big Sky Solar 8 - - - - - - - - - - - - - Blackspring Ridge 1A - Blackspring Ridge 1A Wind Project Wind AB W3978 60987 P200 0.066 693 693 0.0000 - 0.0000 693 - 46 Blackspring Ridge 1A - Blackspring Ridge 1A Wind Project - - - - - - - - - - - - - Blackspring Ridge 1B - Blackspring Ridge 1B Wind Project Wind AB W3979 60988 P201 0.066 766 766 0.0000 - 0.0000 766 - 51 Blackspring Ridge 1B - Blackspring Ridge 1B Wind Project - - - - - - - - - - - - - Blackwell Solar - Blackwell Solar, LLC Solar CA W4587 61892 59524 0.044 36 36 0.0000 - 0.0000 36 - 2 Blackwell Solar - Blackwell Solar, LLC - - - - - - - - - - - - - CA Flats 150 - CA Flats 150 Solar CA W7112 62552 60034 0.044 531 531 0.0000 - 0.0000 531 - 23 CA Flats 150 - CA Flats 150 - - - - - - - - - - - - - California Valley Solar Ranch - Block1 Solar CA W2847 60603 57439 0.044 54 54 0.0000 - 0.0000 54 - 2 California Valley Solar Ranch - Block1 - - - - - - - - - - - - - California Valley Solar Ranch - Block2 Solar CA W3106 60603 57439 0.044 162 162 0.0000 - 0.0000 162 7 - California Valley Solar Ranch - Block2 - - - - - - - - - - - - - California Valley Solar Ranch - Block3 Solar CA W3111 60603 57439 0.044 324 324 0.0000 - 0.0000 324 14 - California Valley Solar Ranch - Block3 - - - - - - - - - - - - - California Valley Solar Ranch - Block4 Solar CA W3187 60603 57439 0.044 130 130 0.0000 - 0.0000 130 6 - California Valley Solar Ranch - Block4 - - - - - - - - - - - - - Cantua Solar Station - Cantua Solar Station Solar CA W2580 61823 57522 0.044 29 29 0.0000 - 0.0000 29 1 - Cantua Solar Station - Cantua Solar Station - - - - - - - - - - - - - CED Corcoran - CED Corcoran Solar CA W3408 60948 58374 0.044 29 29 0.0000 - 0.0000 29 1 - CED Corcoran - CED Corcoran - - - - - - - - - - - - - CED White River 2 Solar - CED White River 2 Solar Solar CA W4111 62045 58973 0.044 10 10 0.0000 - 0.0000 10 - - CED White River 2 Solar - CED White River 2 Solar - - - - - - - - - - - - - CED White River Solar - CED White River Solar Solar CA W3406 60949 58373 0.044 51 51 0.0000 - 0.0000 51 2 - CED White River Solar - CED White River Solar - - - - - - - - - - - - - CID Solar - Corcoran Irrigation District - CID Solar, LLC Solar CA W4227 62285 59183 0.044 58 58 0.0000 - 0.0000 58 3 - CID Solar - Corcoran Irrigation District - CID Solar, LLC - - - - - - - - - - - - - Coleman Powerhouse - Coleman Powerhouse Eligible Hydroelectric CA W347 60037 227 0.044 26 26 0.0000 - 0.0000 26 1 - Coleman Powerhouse - Coleman Powerhouse - - - - - - - - - - - - - Copper Mountain Solar 2 - CMS 2 (1) Solar NV W2818 60990 58017 0.066 93 93 0.0000 - 0.0000 93 6 - Copper Mountain Solar 2 - CMS 2 (1) - - - - - - - - - - - - - Copper Mountain Solar 2 - CMS 2 (2) Solar NV W2943 60990 58017 0.066 82 82 0.0000 - 0.0000 82 5 - Copper Mountain Solar 2 - CMS 2 (2) - - - - - - - - - - - - - Copper Mountain Solar 2 - CMS 2 (3) Solar NV W3201 60990 58017 0.066 93 93 0.0000 - 0.0000 93 6 - Copper Mountain Solar 2 - CMS 2 (3) - - - - - - - - - - - - - Copper Mountain Solar 2 - CMS 2 (4) Solar NV W4555 60990 58017 0.066 104 104 0.0000 - 0.0000 104 7 - Copper Mountain Solar 2 - CMS 2 (4) - - - - - - - - - - - - - Copper Mountain Solar 2 - CMS 2 (5) Solar NV W4589 60990 58017 0.066 104 104 0.0000 - 0.0000 104 7 - Copper Mountain Solar 2 - CMS 2 (5) - - - - - - - - - - - - - Crane Valley Powerhouse - Crane Valley Powerhouse Eligible Hydroelectric CA W349 60039 230 0.044 1 1 0.0000 - 0.0000 1 - - Crane Valley Powerhouse - Crane Valley Powerhouse - - - - - - - - - - - - - Cuyama Solar - Cuyama Solar Solar CA W5611 61891 60043 0.044 109 109 0.0000 - 0.0000 109 5 - Cuyama Solar - Cuyama Solar - - - - - - - - - - - - - De Sabla Powerhouse - De Sabla Powerhouse Eligible Hydroelectric CA W351 60041 232 0.044 25 25 0.0000 - 0.0000 25 1 - De Sabla Powerhouse - De Sabla Powerhouse - - - - - - - - - - - - - DESERT SUNLIGHT 300, LLC - DSL-BLK01 - 04 Solar CA W3793 61068 57993 0.044 403 403 0.0000 - 0.0000 403 18 - DESERT SUNLIGHT 300, LLC - DSL-BLK01 - 04 - - - - - - - - - - - - - DESERT SUNLIGHT 300, LLC - DSL-BLK05 & 06 Solar CA W3798 61068 57993 0.044 132 132 0.0000 - 0.0000 132 6 - DESERT SUNLIGHT 300, LLC - DSL-BLK05 & 06 - - - - - - - - - - - - - DESERT SUNLIGHT 300, LLC - DSL-BLK07 & 08 Solar CA W3800 61068 57993 0.044 64 64 0.0000 - 0.0000 64 3 - DESERT SUNLIGHT 300, LLC - DSL-BLK07 & 08 - - - - - - - - - - - - - DESERT SUNLIGHT 300, LLC - DSL-BLK09 Solar CA W3801 61068 57993 0.044 66 66 0.0000 - 0.0000 66 3 - DESERT SUNLIGHT 300, LLC - DSL-BLK09 - - - - - - - - - - - - - DESERT SUNLIGHT 300, LLC - DSL-BLK10 & 11 Solar CA W3783 61068 57993 0.044 132 132 0.0000 - 0.0000 132 6 - DESERT SUNLIGHT 300, LLC - DSL-BLK10 & 11 - - - - - - - - - - - - - Dutch Flat #2 Powerhouse - Dutch Flat #2 Powerhouse Eligible Hydroelectric CA W488 60264 413 0.044 14 14 0.0000 - 0.0000 14 1 - Dutch Flat #2 Powerhouse - Dutch Flat #2 Powerhouse - - - - - - - - - - - - - Dutch Flat No. 1 Powerhouse - Dutch Flat No. 1 PowerhousEligible Hydroelectric CA W352 60042 237 0.044 78 78 0.0000 - 0.0000 78 3 - Dutch Flat No. 1 Powerhouse - Dutch Flat No. 1 Powerhouse - - - - - - - - - - - - - Five Points Solar Station - Five Points Solar Station Solar CA W2201 61432 59523 0.044 15 15 0.0000 - 0.0000 15 1 - Five Points Solar Station - Five Points Solar Station - - - - - - - - - - - - - FOST A Solar CA W23886 65124 67288 0.044 740 740 #N/A #N/A 0.0000 740 33 - FOST A - - - - - - - - - - - - #N/A FOST B Solar CA W24691 66034 67289 0.044 847 847 #N/A #N/A 0.0000 847 37 - FOST B - - - - - - - - - - - - #N/A FPL Energy Montezuma Wind - FPL Energy Montezuma WWind CA W1745 60543 57201 0.044 122 122 0.0000 - 0.0000 122 5 - FPL Energy Montezuma Wind - FPL Energy Montezuma Wind - - - - - - - - - - - - - Gaskell West 3 Solar CA W15529 63619 61447 0.044 12 12 0.0000 - 0.0000 12 1 - Gaskell West 3 - - - - - - - - - - - - - Gaskell West 4 Solar CA W15585 63617 61448 0.044 11 11 0.0000 - 0.0000 11 - - Gaskell West 4 - - - - - - - - - - - - - Gaskell West 5 Solar CA W15586 63618 61449 0.044 11 11 0.0000 - 0.0000 11 - - Gaskell West 5 - - - - - - - - - - - - - Gates Solar Station - Gates Solar Station Solar CA W3477 62353 57892 0.044 44 44 0.0000 - 0.0000 44 2 - Gates Solar Station - Gates Solar Station - - - - - - - - - - - - - GENESIS SOLAR, LLC - SGN-1 Solar CA W3790 60605 57394 0.044 412 412 0.0000 - 0.0000 412 18 - GENESIS SOLAR, LLC - SGN-1 - - - - - - - - - - - - - GENESIS SOLAR, LLC - SGN2 Solar CA W3791 60605 57394 0.044 411 411 0.0000 - 0.0000 411 18 - GENESIS SOLAR, LLC - SGN2 - - - - - - - - - - - - - Giffen Solar Station - Giffen Solar Station Solar CA W2581 61822 59522 0.044 13 13 0.0000 - 0.0000 13 1 - Giffen Solar Station - Giffen Solar Station - - - - - - - - - - - - - Guernsey Solar Station - Guernsey Solar Station Solar CA W3476 62354 58975 0.044 30 30 0.0000 - 0.0000 30 1 - Guernsey Solar Station - Guernsey Solar Station - - - - - - - - - - - - - Halsey Powerhouse - Halsey Powerhouse Eligible Hydroelectric CA W353 60043 241 0.044 23 23 0.0000 - 0.0000 23 1 - Halsey Powerhouse - Halsey Powerhouse - - - - - - - - - - - - - Hat Creek No. 1 Powerhouse - Hat Creek No. 1 PowerhousEligible Hydroelectric CA W355 60045 243 0.044 32 32 0.0000 - 0.0000 32 1 - Hat Creek No. 1 Powerhouse - Hat Creek No. 1 Powerhouse - - - - - - - - - - - - - Hat Creek No. 2 Powerhouse - Hat Creek No. 2 PowerhousEligible Hydroelectric CA W356 60046 244 0.044 49 49 0.0000 - 0.0000 49 2 - Hat Creek No. 2 Powerhouse - Hat Creek No. 2 Powerhouse - - - - - - - - - - - - -Henrietta Solar Plant - Parrey, LLC Solar CA W5056 61841 58975 0.044 255 255 0.0000 - 0.0000 255 11 - Henrietta Solar Plant - Parrey, LLC - - - - - - - - - - - - - Huron Solar Station - Huron Solar Station Solar CA W2579 61821 57523 0.044 37 37 0.0000 - 0.0000 37 2 - Huron Solar Station - Huron Solar Station - - - - - - - - - - - - - Ivanpah - Unit 1 Solar CA W3189 62273 57073 0.044 289 289 0.0952 28 0.0952 289 13 - Ivanpah - Unit 1 28 - - - - - - - - - - - - Ivanpah - Unit 3 Solar CA W3190 62275 57075 0.044 331 331 0.0952 32 0.0952 331 15 - Ivanpah - Unit 3 32 - - - - - - - - - - - - Java Solar - Java Solar Solar CA W13698 63137 P368 0.044 38 38 0.0000 - 0.0000 38 2 - Java Solar - Java Solar - - - - - - - - - - - - - Kansas - Kansas Solar CA W4192 61263 58985 0.044 34 34 0.0000 - 0.0000 34 1 - Kansas - Kansas - - - - - - - - - - - - - Kent South - Kent South Solar CA W4193 61262 58991 0.044 49 49 0.0000 - 0.0000 49 2 - Kent South - Kent South - - - - - - - - - - - - - Lost Hills - Lost Hills Solar, LLC Solar CA W4586 61893 58712 0.044 62 62 0.0000 - 0.0000 62 3 - Lost Hills - Lost Hills Solar, LLC - - - - - - - - - - - - - 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P. (MP1) - Mammoth Pacific L. P. (MP1)Geothermal CA W417 60306 10480 0.044 75 75 0.0801 6 0.0000 75 3 - Mammoth Pacific L. P. (MP1) - Mammoth Pacific L. P. (MP1) - - - - - - - - - - - - - Mammoth Pacific L. P. I (PLES) - Mammoth Pacific L. P. I (Geothermal CA W416 60315 10481 0.044 131 131 0.0801 10 0.0000 131 6 - Mammoth Pacific L. P. I (PLES) - Mammoth Pacific L. P. 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Bowler Memorial Solar Farm - Westlands Solar Solar CA W3963 61755 58616 0.044 55 55 0.0000 - 0.0000 55 2 - Michael E. Bowler Memorial Solar Farm - Westlands Solar Farm PV-1 - - - - - - - - - - - - - Midway Solar Farm I - Midway Solar Farm I Solar CA W5367 61295 60336 0.044 180 180 0.0000 - 0.0000 180 8 - Midway Solar Farm I - Midway Solar Farm I - - - - - - - - - - - - - Mojave Solar Project - Mojave Solar Project - Alpha Solar CA W4255 60848 57331 0.044 440 440 0.0000 - 0.0000 440 19 - Mojave Solar Project - Mojave Solar Project - Alpha - - - - - - - - - - - - - Mojave Solar Project - Mojave Solar Project - Beta Solar CA W4450 60848 57331 0.044 449 449 0.0000 - 0.0000 449 20 - Mojave Solar Project - Mojave Solar Project - Beta - - - - - - - - - - - - - Montezuma Wind II - Nextera Energy Montezuma II Wind Wind CA W2400 61345 57701 0.044 261 261 0.0000 - 0.0000 261 11 - Montezuma Wind II - Nextera Energy Montezuma II Wind - - - - - - - - - - - - - Nevada Irrigation District - Bowman Hydro Project Eligible Hydroelectric CA W635 60171 50546 0.044 17 17 0.0000 - 0.0000 17 1 - Nevada Irrigation District - Bowman Hydro Project - - - - - - - - - - - - - Newcastle Powerhouse - Newcastle Powerhouse Eligible Hydroelectric CA W364 60053 632 0.044 3 3 0.0000 - 0.0000 3 - - Newcastle Powerhouse - Newcastle Powerhouse - - - - - - - - - - - - - North Sky River - North Sky River - Phase I Wind CA W3206 61385 58154 0.044 483 483 0.0000 - 0.0000 483 21 - North Sky River - North Sky River - Phase I - - - - - - - - - - - - - North Star Solar - North Star Solar, LLC Solar CA W4629 61198 58713 0.044 188 188 0.0000 - 0.0000 188 8 - North Star Solar - North Star Solar, LLC - - - - - - - - - - - - - Old River One - Old River One Solar CA W4194 60853 58986 0.044 53 53 0.0000 - 0.0000 53 2 - Old River One - Old River One - - - - - - - - - - - - - Orion Solar I - Orion Solar I, LLC Solar CA W3981 61570 58718 0.044 37 37 0.0000 - 0.0000 37 2 - Orion Solar I - Orion Solar I, LLC - - - - - - - - - - - - - Pacific Lumber Co. - Pacific Lumber Co. Unit 1 Biomass & Biogas CA W645 60083 50049 0.044 20,768 20,768 2.3536 48,880 0.0550 20,768 914 - Pacific Lumber Co. - Pacific Lumber Co. Unit 1 1,142 - - - - - - - - - - - - Pacific Lumber Co. - Pacific Lumber Co. Unit 2 Biomass & Biogas CA W790 60083 50049 0.044 34,610 30,000 4,610 2.3536 10,850 0.0550 4,610 203 - Pacific Lumber Co. - Pacific Lumber Co. Unit 2 254 - - - - - - - - - - - - Pacific Lumber Co. - Pacific Lumber Co. Unit 3 Biomass & Biogas CA W791 60083 50049 0.044 34,613 30,000 4,613 2.3536 10,857 0.0550 4,613 203 - Pacific Lumber Co. - Pacific Lumber Co. Unit 3 254 - - - - - - - - - - - - Phoenix Powerhouse - Phoenix Powerhouse Eligible Hydroelectric CA W366 60054 264 0.044 8 8 0.0000 - 0.0000 8 - - Phoenix Powerhouse - Phoenix Powerhouse - - - - - - - - - - - - -Portal Ridge Solar C - Portal Ridge Solar C Solar CA W5211 61684 60311 0.044 45 45 0.0000 - 0.0000 45 2 - Portal Ridge Solar C - Portal Ridge Solar C - - - - - - - - - - - - - Potrero Hills Energy Producers - Potrero Hills Energy ProduBiomass & Biogas CA W4867 63116 59952 0.044 92 92 0.5608 52 0.0029 92 4 - Potrero Hills Energy Producers - Potrero Hills Energy Producers, LLC 0 - - - - - - - - - - - - RE Astoria 1 - RE Astoria 1 Solar CA W4930 62284 59976 0.044 311 311 0.0000 - 0.0000 311 14 - RE Astoria 1 - RE Astoria 1 - - - - - - - - - - - - - RE Kansas South - RE Kansas South Solar CA W3109 61264 58148 0.044 56 56 0.0000 - 0.0000 56 2 - RE Kansas South - RE Kansas South - - - - - - - - - - - - - Redwood Coast Airport Microgrid - Redwood Coast Airport Solar CA W12135 64947 64766 0.044 1,669 1,669 0.0000 - 0.0000 1,669 73 - Redwood Coast Airport Microgrid - Redwood Coast Airport Microgrid - - - - - - - - - - - - - Rising Tree Wind Farm II LLC - Rising Tree Wind Farm II LLCWind CA W4445 62426 57621 0.044 75 75 0.0000 - 0.0000 75 3 - Rising Tree Wind Farm II LLC - Rising Tree Wind Farm II LLC - - - - - - - - - - - - - Rock Creek - Rock Creek Unit 1 Eligible Hydroelectric CA W2643 62269 50987 0.044 11 11 0.0000 - 0.0000 11 - - Rock Creek - Rock Creek Unit 1 - - - - - - - - - - - - - Rock Creek - Rock Creek Unit 2 Eligible Hydroelectric CA W2644 62269 50987 0.044 33 33 0.0000 - 0.0000 33 1 - Rock Creek - Rock Creek Unit 2 - - - - - - - - - - - - - Rollins Powerhouse - Rollins Powerhouse Eligible Hydroelectric CA W699 60265 34 0.044 36 36 0.0000 - 0.0000 36 2 - Rollins Powerhouse - Rollins Powerhouse - - - - - - - - - - - - - San Joaquin No. 1-A Powerhouse - San Joaquin No. 1-A PEligible Hydroelectric CA W345 60056 278 0.044 1 1 0.0000 - 0.0000 1 - - San Joaquin No. 1-A Powerhouse - San Joaquin No. 1-A Powerhouse - - - - - - - - - - - - - Sandrini Sol 1 Solar CA W18934 64279 65663 0.044 274,316 72,467 201,849 0.0000 - 0.0000 195,159 5,819 870 8,881 1 Sandrini Sol 1 - - - - - - - - Sandrini Sol 1 Solar 1 0 - Shafter Solar, LLC - Shafter Solar, LLC Solar CA W4680 62325 59408 0.044 21 21 0.0000 - 0.0000 21 1 - Shafter Solar, LLC - Shafter Solar, LLC - - - - - - - - - - - - - Shiloh IV Wind Project, LLC - Shiloh IV Wind Project, LLC Wind CA W2780 61617 57725 0.044 384 384 0.0000 - 0.0000 384 17 - Shiloh IV Wind Project, LLC - Shiloh IV Wind Project, LLC - - - - - - - - - - - - - Sierra Pacific Burney Facility - Sierra Pacific Industry (Burn Biomass & Biogas CA W667 60087 50110 0.044 93 93 0.4549 42 0.0090 93 4 - Sierra Pacific Burney Facility - Sierra Pacific Industry (Burney) 1 - - - - - - - - - - - - Sierra Pacific Ind. (Lincoln) - Sierra Pacific Industry (LincolnBiomass & Biogas CA W668 60088 10144 0.044 52 52 0.5462 28 0.0108 52 2 - Sierra Pacific Ind. (Lincoln) - Sierra Pacific Industry (Lincoln) 1 - - - - - - - - - - - - Sierra Pacific Ind. (Quincy) - Sierra Pacific Industry (QuincyBiomass & Biogas CA W669 60089 50112 0.044 203 203 2.2532 457 0.0473 203 9 - Sierra Pacific Ind. (Quincy) - Sierra Pacific Industry (Quincy) 10 - - - - - - - - - - - -Sierra Pacific Sonora - Sierra Pacific Sonora Biomass & Biogas CA W852 60576 54517 0.044 37 37 3.5065 130 0.0772 37 2 - Sierra Pacific Sonora - Sierra Pacific Sonora 3 - - - - - - - - - - - - Snow Mtn Hydro (Cove) - Cove Eligible Hydroelectric CA W674 60178 10707 0.044 17,353 17,353 0.0000 - 0.0000 11,535 5,818 764 - Snow Mtn Hydro (Cove) - Cove - - - - - - - - - - - - - Solar Alpine LLC - Solar Alpine LLC Solar CA W2872 60755 57295 0.044 118 118 0.0000 - 0.0000 118 5 - Solar Alpine LLC - Solar Alpine LLC - - - - - - - - - - - - - South Powerhouse - South Powerhouse Eligible Hydroelectric CA W370 60059 280 0.044 7 7 0.0000 - 0.0000 7 - - South Powerhouse - South Powerhouse - - - - - - - - - - - - - Spaulding No. 1 Powerhouse - Spaulding No. 1 PowerhousEligible Hydroelectric CA W371 60060 281 0.044 13 13 0.0000 - 0.0000 13 1 - Spaulding No. 1 Powerhouse - Spaulding No. 1 Powerhouse - - - - - - - - - - - - - Spaulding No. 2 Powerhouse - Spaulding No. 2 PowerhousEligible Hydroelectric CA W372 60061 282 0.044 7 7 0.0000 - 0.0000 7 - - Spaulding No. 2 Powerhouse - Spaulding No. 2 Powerhouse - - - - - - - - - - - - - Spaulding No. 3 Powerhouse - Spaulding No. 3 PowerhousEligible Hydroelectric CA W373 60062 283 0.044 22 22 0.0000 - 0.0000 22 1 - Spaulding No. 3 Powerhouse - Spaulding No. 3 Powerhouse - - - - - - - - - - - - - SPI Anderson 2 - SPI Anderson 2 Biomass & Biogas CA W4674 61146 59658 0.044 167 167 0.4128 69 0.0137 167 7 - SPI Anderson 2 - SPI Anderson 2 2 - - - - - - - - - - - - Spring Gap Powerhouse - Spring Gap Powerhouse Eligible Hydroelectric CA W374 60063 284 0.044 16 16 0.0000 - 0.0000 16 1 - Spring Gap Powerhouse - Spring Gap Powerhouse - - - - - - - - - - - - - SPS Alpaugh 50 - SPS Alpaugh 50 Solar CA W2826 60945 58003 0.044 67 67 0.0000 - 0.0000 67 3 - SPS Alpaugh 50 - SPS Alpaugh 50 - - - - - - - - - - - - - SPS Alpaugh North - SPS Alpaugh North Solar CA W2825 60946 58002 0.044 24 24 0.0000 - 0.0000 24 1 - SPS Alpaugh North - SPS Alpaugh North - - - - - - - - - - - - - Stockton Biomass - Stockton Biomass Biomass & Biogas CA W3540 60964 54238 0.044 420 420 1.3744 577 0.0300 420 - 18 Stockton Biomass - Stockton Biomass 13 - - - - - - - - - - - - Stroud Solar Station - Stroud Solar Station Solar CA W2203 61434 57497 0.044 21 21 0.0000 - 0.0000 21 - 1 Stroud Solar Station - Stroud Solar Station - - - - - - - - - - - - - Sunray 2- SEGS II - Sunray 2- SEGS II Solar CA W466 62694 10437 0.044 66 66 0.0000 - 0.0000 66 - 3 Sunray 2- SEGS II - Sunray 2- SEGS II - - - - - - - - - - - - - Sunshine Gas Producers - Sunshine Gas Producers, L.L.C.Biomass & Biogas CA W4144 60815 58429 0.044 225 225 0.6985 157 0.0036 225 - 10 Sunshine Gas Producers - Sunshine Gas Producers, L.L.C. 1 - - - - - - - - - - - - Toadtown Powerhouse - Toadtown Powerhouse Eligible Hydroelectric CA W375 60064 714 0.044 2 2 0.0000 - 0.0000 2 - - Toadtown Powerhouse - Toadtown Powerhouse - - - - - - - - - - - - - Topaz Solar Farms LLC - Topaz 10-16 Solar CA W3226 61698 57695 0.044 437 437 0.0000 - 0.0000 437 19 - Topaz Solar Farms LLC - Topaz 10-16 - - - - - - - - - - - - - Topaz Solar Farms LLC - Topaz 17 - 20 Solar CA W3227 61698 57695 0.044 239 239 0.0000 - 0.0000 239 11 - Topaz Solar Farms LLC - Topaz 17 - 20 - - - - - - - - - - - - - Topaz Solar Farms LLC - Topaz 1-9 Solar CA W3193 61698 57695 0.044 604 604 0.0000 - 0.0000 604 27 - Topaz Solar Farms LLC - Topaz 1-9 - - - - - - - - - - - - - Topaz Solar Farms LLC - Topaz 21 - 22 Solar CA W3229 61698 57695 0.044 101 101 0.0000 - 0.0000 101 4 - Topaz Solar Farms LLC - Topaz 21 - 22 - - - - - - - - - - - - - Vaca Dixon Solar Station - Vaca Dixon Solar Station Solar CA W1455 60966 57041 0.044 4 4 0.0000 - 0.0000 4 - - Vaca Dixon Solar Station - Vaca Dixon Solar Station - - - - - - - - - - - - - Vasco Winds - Vasco Winds Wind CA W2401 61344 57700 0.044 263 263 0.0000 - 0.0000 263 12 - Vasco Winds - Vasco Winds - - - - - - - - - - - - - Volta No. 1 Powerhouse - Volta No. 1 Powerhouse Eligible Hydroelectric CA W377 60066 290 0.044 32 32 0.0000 - 0.0000 32 1 - Volta No. 1 Powerhouse - Volta No. 1 Powerhouse - - - - - - - - - - - - - Volta No. 2 Powerhouse - Volta No. 2 Powerhouse Eligible Hydroelectric CA W378 60067 180 0.044 4 4 0.0000 - 0.0000 4 - - Volta No. 2 Powerhouse - Volta No. 2 Powerhouse - - - - - - - - - - - - - West Gates Solar Station - West Gates Solar Station Solar CA W3478 62352 58206 0.044 19 19 0.0000 - 0.0000 19 1 - West Gates Solar Station - West Gates Solar Station - - - - - - - - - - - - - West Point Powerhouse - West Point Powerhouse Eligible Hydroelectric CA W379 60068 291 0.044 29 29 0.0000 - 0.0000 29 1 - West Point Powerhouse - West Point Powerhouse - - - - - - - - - - - - - Western Antelope Blue Sky Ranch A - WABSRA Solar CA W4264 61517 58626 0.044 61 61 0.0000 - 0.0000 61 3 - Western Antelope Blue Sky Ranch A - WABSRA - - - - - - - - - - - - - Westside Solar Station - Westside Solar Station Solar CA W2202 61433 57499 0.044 13 13 0.0000 - 0.0000 13 1 - Westside Solar Station - Westside Solar Station - - - - - - - - - - - - - Wise No. 1 Powerhouse - Wise No. 1 Powerhouse Eligible Hydroelectric CA W380 60069 292 0.044 29 29 0.0000 - 0.0000 29 1 - Wise No. 1 Powerhouse - Wise No. 1 Powerhouse - - - - - - - - - - - - - Diablo Winds, LLC - Diablo Winds, LLC Wind CA W762 60030 56271 0.044 21 21 0.0000 - 0.0000 21 1 - Diablo Winds, LLC - Diablo Winds, LLC - - - - - - - - - - - - - Balch #1 PH Large Hydroelectric 217 0.066 591 222 369 0.0000 - 0.0000 369 24 - Balch #1 PH - - - - - - - - - - - - - Balch #2 PH Large Hydroelectric 218 0.066 2,871 1,162 1,709 0.0000 - 0.0000 1,709 113 - Balch #2 PH - - - - - - - - - - - - - Belden Large Hydroelectric 219 0.066 1,807 214 1,593 0.0000 - 0.0000 1,593 105 - Belden - - - - - - - - - - - - - Bucks Creek Large Hydroelectric 220 0.066 1,616 921 695 0.0000 - 0.0000 695 46 - Bucks Creek - - - - - - - - - - - - - Butt Valley Large Hydroelectric 221 0.066 1,170 333 837 0.0000 - 0.0000 837 55 - Butt Valley - - - - - - - - - - - - - Caribou 1 Large Hydroelectric 222 0.066 2,228 1,178 1,050 0.0000 - 0.0000 1,050 69 - Caribou 1 - - - - - - - - - - - - - Caribou 2 Large Hydroelectric 223 0.066 3,616 1,380 2,236 0.0000 - 0.0000 2,236 148 - Caribou 2 - - - - - - - - - - - - - Cresta Large Hydroelectric 231 0.066 2,899 1,925 974 0.0000 - 0.0000 974 64 - Cresta - - - - - - - - - - - - - Drum #1 Large Hydroelectric 235 0.066 119 22 97 0.0000 - 0.0000 97 6 - Drum #1 - - - - - - - - - - - - - Drum #2 Large Hydroelectric 236 0.066 1,295 220 1,075 0.0000 - 0.0000 1,075 71 - Drum #2 - - - - - - - - - - - - - Electra Large Hydroelectric 239 0.066 2,407 1,242 1,165 0.0000 - 0.0000 1,165 77 - Electra - - - - - - - - - - - - -Haas Large Hydroelectric 240 0.066 2,130 371 1,759 0.0000 - 0.0000 1,759 116 - Haas - - - - - - - - - - - - - James B Black Large Hydroelectric 249 0.066 5,592 2,890 2,702 0.0000 - 0.0000 2,702 178 - James B Black - - - - - - - - - - - - - Kerckhoff #2 PH Large Hydroelectric 682 0.066 3,484 2,288 1,196 0.0000 - 0.0000 1,196 79 - Kerckhoff #2 PH - - - - - - - - - - - - - Kings River Large Hydroelectric 254 0.066 652 19 633 0.0000 - 0.0000 633 42 - Kings River - - - - - - - - - - - - - Pit 1 Large Hydroelectric 265 0.066 2,171 1,184 987 0.0000 - 0.0000 987 65 - Pit 1 - - - - - - - - - - - - - Pit 3 Large Hydroelectric 266 0.066 3,185 1,773 1,412 0.0000 - 0.0000 1,412 93 - Pit 3 - - - - - - - - - - - - -Pit 4 Large Hydroelectric 267 0.066 3,349 1,691 1,658 0.0000 - 0.0000 1,658 109 - Pit 4 - - - - - - - - - - - - - Pit 5 Large Hydroelectric 268 0.066 5,690 2,871 2,819 0.0000 - 0.0000 2,819 186 - Pit 5 - - - - - - - - - - - - - Pit 6 Large Hydroelectric 269 0.066 2,214 926 1,288 0.0000 - 0.0000 1,288 85 - Pit 6 - - - - - - - - - - - - -Pit 7 Large Hydroelectric 270 0.066 3,716 1,941 1,775 0.0000 - 0.0000 1,775 117 - Pit 7 - - - - - - - - - - - - - Poe Large Hydroelectric 272 0.066 2,891 1,430 1,461 0.0000 - 0.0000 1,461 96 - Poe - - - - - - - - - - - - -Rock Creek Large Hydroelectric 275 0.066 4,609 2,670 1,939 0.0000 - 0.0000 1,939 128 - Rock Creek - - - - - - - - - - - - - Salt Springs Large Hydroelectric 279 0.066 924 218 706 0.0000 - 0.0000 706 47 - Salt Springs - - - - - - - - - - - - - Stanislaus Large Hydroelectric 285 0.066 1,516 378 1,138 0.0000 - 0.0000 1,138 75 - Stanislaus - - - - - - - - - - - - - Tiger Creek Large Hydroelectric 287 0.066 1,692 416 1,276 0.0000 - 0.0000 1,276 84 - Tiger Creek - - - - - - - - - - - - - NID-Chicago Park Large Hydroelectric 412 0.066 528 113 415 0.0000 - 0.0000 415 27 - NID-Chicago Park - - - - - - - - - - - - - Diablo Canyon Power Plant Unit 1 Nuclear 6099 0.066 29,311 29,311 0.0000 - 0.0000 29,311 1,935 - Diablo Canyon Power Plant Unit 1 - - - - - - - - - - - - - Diablo Canyon Power Plant Unit 2 Nuclear 6099 0.066 8,434 8,434 0.0000 - 0.0000 8,434 - 557 Diablo Canyon Power Plant Unit 2 - - - - - - - - - - - - - Colgate Powerhouse Unit 1 Large Hydroelectric CA 454 0.044 78,196 78,196 0.0000 - 0.0000 53,609 3,441 24,587 - Colgate Powerhouse Unit 1 - - - - - - - - - - - - - Colgate Powerhouse Unit 2 Large Hydroelectric CA 454 0.044 78,122 78,122 0.0000 - 0.0000 78,122 - 3,437 Colgate Powerhouse Unit 2 - - - - - - - - - - - - - Narrows Powerhouse Unit 2 Large Hydroelectric CA 455 0.044 43,682 43,682 0.0000 - 0.0000 43,682 - 1,922 Narrows Powerhouse Unit 2 - - - - - - - - - - - - -

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0.066 - #N/A #N/A 0.0000 - - - - - - - - - - - - - - #N/A Instructions1. Enter electricity portfolio names in cells Q27-V27, as needed.2. Enter the megawatt hours (MWh) of retail sales associated with electricity portfolios in cells Q25-V25, as needed, and the MWh associated with other end uses in cell W25.3. In the table beginning with cell A28, enter information about all specified purchases. All fields in white should be filled out. Fields in grey auto-populate as needed and should not be filled out.4. Default loss factors will auto-populate based on resource location. Enter a custom loss factor if applicable. All custom loss factors require additional documentation.5. If a resource’s losses are covered by the generation seller under contract, select “Yes” in the relevant cell in column M: “Specified Losses Covered by Seller?” 6. For firmed-&-shaped procurements specifically, enter all fields from step 3. Additionally, enter the EIA ID of the substitute power in the "EIA ID of Delivered Energy" field.7. For firmed-&-shaped procurements eligible for grandfathered GHG emissions, select "Yes" in the relevant field in column L: "Eligible for Firmed & Shaped Grandfathering?"8. Proxy EIA IDs for unspecified power and specified system mixes from asset-controlling suppliers have been provided. Enter "Unspecified Power", "BPA", or "Tacoma Power" as applicable.9. Proxy EIA IDs for aggregated reporting of WAPA CVP or PCIA resources have been provided. Enter "CVP", "PCIA Solar", "PCIA Wind", "PCIA Eligible Hydro", or "PCIA Large Hydro" as applicable.10. Only unspecified imports purchased directly from a seller under contract or ACS unspecified power procurements must be entered as line items; any additional unspecified power is calculated automatically in individual electricity portfolio tables after all specified resources are allocated.11. Allocate net MWhs procured to each electricity portfolio until the loads are balanced across each portfolio. If the total Net MWhs Procured exceeds the total retail sales of all portfolios, allocate only enough MWh to meet the retail sales of each portfolio.12. If electricity portfolio loads are balanced and net MWhs remain, allocate net MWhs to cover losses in the column starting with cell X28. This will add new losses, resulting in a new net short of unmet load in Cell X26. For retail suppliers that want to cover 100% of their loss-adjusted load with specified procurements, continue allocating specified procurement in Column X until Cell X26 shows no unmet load. 33 Instructions

1. In the table starting in cell A13, select the appropriate retail portfolio from the drop-down list in column A and enter the Facility Name, Fuel Type, State or Province, RPS ID, and Total Retired Unbundled RECs (in MWh) for each facility

TOTAL ALLOCATIONS
Retail Portfolio Total Retired (in MWh)
REpower 0
REpower+ 0
Electricity Portfolio Name 3 0
Electricity Portfolio Name 4 0
Electricity Portfolio Name 5 0
Electricity Portfolio Name 6 0

RETIRED UNBUNDLED RECS
Retail Portfolio Facility Name Fuel Type State or Province RPS ID Total Retired (in MWh) 34 2025 PCL Data*
Emissions, Power Sources, Unbundled RECs REpower REpower+ Electricity
Portfolio Name 3
Electricity Portfolio
Name 4
Electricity Portfolio
Name 5
Electricity Portfolio
Name 6
Total Loss-Adjusted Load
Retail Sales and Loss-Adjusted Load 500,734 14,705 0 0 0 0 540,896 GHG Emissions Intensity (lbs CO2e/MWh) 8 0 #DIV/0! #DIV/0! #DIV/0! #DIV/0! 7 ■ Renewables and Zero-Carbon Resources 100% 100% #DIV/0! #DIV/0! #DIV/0! #DIV/0! 100% ■ Fossil Fuels 0% 0% #DIV/0! #DIV/0! #DIV/0! #DIV/0! 0% Biomass & Biogas 6% 0% #DIV/0! #DIV/0! #DIV/0! #DIV/0! 6% Geothermal 0% 0% #DIV/0! #DIV/0! #DIV/0! #DIV/0! 0%
Eligible Hydroelectric 2% 40% #DIV/0! #DIV/0! #DIV/0! #DIV/0! 3% Solar 42% 40% #DIV/0! #DIV/0! #DIV/0! #DIV/0! 40%
Wind 0% 21% #DIV/0! #DIV/0! #DIV/0! #DIV/0! 1%
RPS Eligible Renewables - Subtotal 50% 100% #DIV/0! #DIV/0! #DIV/0! #DIV/0! 50% Large Hydroelectric 42% 0% #DIV/0! #DIV/0! #DIV/0! #DIV/0! 43% Nuclear 8% 0% #DIV/0! #DIV/0! #DIV/0! #DIV/0! 7%
Emerging Technologies 0% 0% #DIV/0! #DIV/0! #DIV/0! #DIV/0! 0% Other 0% 0% #DIV/0! #DIV/0! #DIV/0! #DIV/0! 0%
Natural Gas 0% 0% #DIV/0! #DIV/0! #DIV/0! #DIV/0! 0%
Coal & Petroleum 0% 0% #DIV/0! #DIV/0! #DIV/0! #DIV/0! 0% Unspecified Power - Total 0% 0% #DIV/0! #DIV/0! #DIV/0! #DIV/0! 0% Retail Sales Covered by Retired Unbundled RECs 0% 0% #DIV/0! #DIV/0! #DIV/0! #DIV/0! - *NOTE: The figures above are preliminary.

Staff will calculate the GHG emissions factor and fuel mix breakdown (percentage derived from renewables and zero-carbon resources or fossil fuels) of unspecified power after data from all reporting entities is submitted. 35 2025 POWER SOURCE DISCLOSURE ANNUAL REPORT

ATTESTATION FORM
For the Year Ending December 31, 2025
Redwood Coast Energy Authority
Name: _____________________________________________________________ Representing (Retail Supplier):_________________________________________ Signature: __________________________________________________________ Dated: _____________________________________________________________ Executed at: ________________________________________________________ I, [print name] ___________________________________________________, [title] _________________________, declare under penalty of perjury, that the information provided in this report is true and correct and that I, as an authorized agent of [retail supplier], _____________________________, have authority to submit this report on the retail supplier's behalf. I further declare that all of the electricity claimed as specified purchases as shown in this report was sold once and only once to retail customers.

Forrest Novotny
Compliance Technician
Redwood Coast Energy Authority
Forrest Novotny
Redwood Coast Energy Authority
7/27/2026
633 3rd St. Eureka, CA 95501
36

Staff Report
Agenda Item # 11.1
Information
Agenda Date September 24, 2026
To Board of Directors
Prepared by Richard Engel, Director of Power Resources
Subject Annual Report on Humboldt Sawmill Company Memorandum of Understanding Background
When authorizing extension of RCEA’s power purchase agreement (PPA) for biomass energy with Humboldt Sawmill Company (HSC) in April 2021, RCEA’s Board directed staff to "periodically review the contract…assessing current alternate biomass uses and other environmental considerations." To create a framework for the requested periodic review, staff negotiated a memorandum of understanding (MOU) between RCEA and HSC, which the RCEA Board adopted in September 2021. One provision of the MOU is as follows:

Annually on or around May 1 and continuing until the termination of the PPA, representatives of the Parties will meet to review the terms of the PPA and to discuss the continued viability of biomass power production by the HSC facility relative to other potential or actual uses of the biomass feedstock by HSC or other entities.

The MOU also calls for HSC to provide data on plant performance on request; types, quantities, and sources of biomass feedstock; and plant emissions. HSC has generally been responsive to specific data requested by RCEA staff under the MOU.

As a reminder, the MOU’s purpose is not to terminate or otherwise override the terms of the PPA. As the MOU states: “This MOU does not and is not intended to supersede, replace, or subordinate any provisions, representations, covenants, rights, or obligations in the PPA.” While the MOU does not allow for early termination of the biomass PPA, it could help form a pathway for alternative use of the biomass plant’s feedstock material once the current PPA’s term expires.

Summary
Data provided for the past reporting year included:
• An updated table providing data requested by RCEA, including:
o Monthly amounts of biomass feedstock, broken down by geographic origin (inside or outside Humboldt County) and supplier (sourced internally from Humboldt Redwood Company or Mendocino Redwood Company or externally)
o Monthly use of biomass and auxiliary diesel fuel, electric output to RCEA and for onsite use, and thermal energy recovered for industrial use
37

o Annual total emissions of greenhouse gases (biogenic and non-biogenic) and a number of criteria pollutants
• A set of “Co-Gen Monthly Monitoring Reports” filed with the North Coast Unified Air Quality Management District (Air District) by HSC that disclose startup and shutdown events, equipment breakdowns and malfunctions, and emergency events. The reports include extensive tables of emissions data for the plant at hourly or more frequent intervals. • Quarterly opacity reports providing data from opacity sensors in the boiler stacks to confirm the sensors are working properly.
• Quarterly cylinder gas audits on the plant’s continuous emission monitoring systems in each boiler’s stack to confirm the monitoring systems are working properly. • A throughput report showing monthly total amounts of steam produced and amounts of biomass and diesel fuel combusted for each of the plant’s boilers.

In addition to the data provided by HSC, there are three items of special note this year. • HSC reported that they received no new notices of violation from the Air District in the past reporting year. This was the first reporting year since the MOU reporting cycle began in 2021 that HSC has had no notices of violation.
• RCEA requested and received from the Air District a draft Health Risk Assessment (HRA) Report prepared for HSC at the Air District’s direction by Landau Associates. The assessment, which was conducted per the Air Toxics “Hot Spots” Information and Assessment Act of 1987 (Assembly Bill 2588) and delivered to the Air District on June 15, 2026, modeled and quantified impacts of HSC plant emissions on health of populations near the plant. The draft report found that cancer risks fall below the Air District’s notification or remediation thresholds. The draft report is subject to review and revision by the Air District and the State-level Office of Environmental Health Hazard Assessment before receiving final approval.
• The US Environmental Protection Agency issued an order denying petition dated May 5, 2026, in response to the January 1, 2025, petition from the Environmental Protection Information Center and the Humboldt Coalition for Clean Energy that staff reported to the Board last year. That petition asked the EPA to object to the Title V operating permit issued to HSC by the Air District.

The fifth annual meeting between RCEA and HSC staff per the MOU took place at HSC’s Scotia headquarters on June 16, 2026. The materials listed above were reviewed, and HSC management described improvements they have recently made at the plant to improve efficiency and reduce emissions. For example, they noted that capping off a steam line that is no longer needed reduced cold startup time following extended shutdowns from 10 hours to five hours, reducing the amount of diesel needed as auxiliary fuel during these startups.

RCEA staff reviewed the materials provided by HSC and then shared them with members of the Biomass Technical Advisory Group (BTAG). RCEA staff attempted to convene a meeting of BTAG to discuss the HSC materials but were unable to identify a date and time this summer when more than a very small number of members were available to attend. Staff instead asked the BTAG members to provide written comments on the materials and provided a follow-up reminder. The only comments received prior to publication of this report were from HSC leadership indicating they had no responses to the prompts 38

provided, and one BTAG member noting that other sources of PM 2.5 in the vicinity of the plant such as airborne dust from the log yard and river bar during the dry season should be studied.

The materials provided by HSC, the draft HRA provided by NCUAQMD, and the US EPA's order denying petition are available for review on the Energy Sources page of RCEA’s website at https://redwoodenergy.org/about/energy-sources/ under the “Local Biomass Energy” subheading.

Staff asked at the annual meeting what progress HSC has made on their ongoing investigation of alternative uses for their biomass plant feedstock. HSC leadership reported that they have continued to investigate alternative biomass uses at their Mendocino County facility, but to date they have not committed to move forward with development of a new project, given the currently poor economics of the alternatives they have evaluated.

On September 8, staff presented the materials described above to RCEA’s Community Advisory Committee for review and discussion. Committee members asked about the high level of carbon dioxide emissions per unit of electric generation from the facility compared with other biomass facilities, which is likely connected with the relatively high moisture content of biomass fuels in the North Coast area.

Notwithstanding the findings of the draft health risk assessment, committee members expressed concern about exposure to particulate matter from the plant, especially given the close proximity of the Scotia school. The committee noted the low participation from the Biomass Technical Advisory Group in reviewing this year's materials and discussed the need to explore alternative clean energy sources, including potential presentations from companies developing wave and tide energy technologies. One committee member commented that the committee’s comments and requests for information over the past few years have helped to make HSC more transparent regarding its operations and emissions.

Alignment with RCEA’s Strategic Plan
RCEA’s consultations with HSC in implementing the terms of the MOU are in keeping with the following strategies in the RePower Humboldt plan:
• 4.1.11.3 Investigate the Impacts of Biomass Emissions • 4.1.11.6 Plan for a Long-Term Transition Away from Direct Combustion of Forest Derived Biomass and Toward Lower-Impact Uses of this Material
Review of HSC’s reporting by BTAG is in keeping with the RePower Humboldt plan’s direction:
• 4.1.11.4 Establish a Biomass Technical Advisory Committee.

However, as noted no discussion with or review by BTAG took place this year.

Equity Impacts
This is an information only item and has no associated equity impacts.

Financial Impact
This is an information only item and has no associated financial impacts. 39

Staff Recommendation
Information item only.

Attachments

1. Draft Health Risk Assessment Report (Executive Summary, full text available via link below) See https://redwoodenergy.org/about/energy-sources/ under the “Local Biomass Energy” subheading for a link to the materials mentioned in this report that were provided by Humboldt Sawmill Company, the North Coast Unified Air Quality Management District, and the US Environmental Protection Agency.
40 North Coast Unified
Air Quality Management District
707 L Street, Eureka, CA 95501
(707) 443-3093
www.ncuaqmd.org
June 15, 2026
RE: Health Risk Assessment (HRA) Report for the Humboldt Saw Mill Company (HSC) dated June 15, 2026 is still considered a “DRAFT” document On June 15, 2026, the Humboldt Saw Mill Company (HSC) submitted the attached Health Risk Assessment (HRA) Report to the North Coast Unified Air Quality Management District (District). The District considers the attached document a “DRAFT” document until final review and approval by the District per the California Health & Safety Code (H&SC).

Once a completeness review of the emission impact and modeling data is performed, the District will submit the draft HRA to the Office of Environmental Health Hazard Assessment (OEHHA) which then has up to 180 days to review per H&SC §44361. After receiving OEHHA’s comments and findings related to health effects, the District will continue to consult with appropriate agencies to evaluate the emissions impact and modeling data contained within the HRA. Under H&SC §44362(a), the District has up to one year from the date of receipt to approve, or return for revision and resubmission and then approve the “final” HRA.

Upon final approval of the HRA, the District will then evaluate whether HSC may be required to provide notice to all affected parties per H&SC §44362(b). 41 SEATTLE
155 NE 100th St, Ste 302, Seattle, WA 98125 T 206.631.8680 landauinc.com AIR TOXICS HOT SPOTS (AB 2588)

HEALTH RISK ASSESSMENT REPORT
Humboldt Sawmill
Scotia, California
June 15, 2026
Prepared for
Humboldt Sawmill Co., LLC
169 Main Street
Scotia, California
Note:

This draft report is subject to review and revision by the North Coast Unified Air Quality Management District and the California Office of Environmental Health Hazard Assessment.

See https://redwoodenergy.org/about/energy-sources/ under the "Local Biomass Energy" heading for a link to the full draft report.
42 Air Toxics Hot Spots (AB 2588) Health Risk Assessment Report Humboldt Sawmill Company—Scotia, California
2125002.020
June 15, 2026 iii landauinc.com

EXECUTIVE SUMMARY
As requested by the North Coast Unified Air Quality Management District (NCUAQMD; the District), this Air Toxics Health Risk Assessment (HRA) report has been prepared by Landau Associates, Inc. (Landau) for Humboldt Sawmill Company (HSC), which owns and operates a lumber manufacturing facility located in Scotia, California (“the Facility”), pursuant to the Air Toxics “Hot Spots” Information and Assessment Act of 1987 (Assembly Bill [AB]2588).

Under AB2588, the Facility (Facility Identification Number 60) is required to quantify emissions of listed substances (i.e., AB2588 substances, which are commonly referred to as toxic air contaminants or TACs) attributable to Facility equipment and operations, and the potential health impacts of those emissions on adjacent populations. To meet the statutory requirements under AB2588, HSC has retained Landau to quantify the potential health impacts of those emissions on adjacent populations using approved information and methodologies.

Air Toxics “Hot Spots” AB2588
The primary goals of AB2588 are to require the collection of emission data, identify facilities having localized impacts, quantify health risks, notify nearby exposed populations, and/or implement emission or risk reduction programs if the estimated health risks exceed certain threshold levels. The threshold levels that are considered significant for notification or risk reduction purposes are not defined in AB2588, and are left to the discretion of the District.

On the subject of notification, AB2588 states:
“Upon approval of the health risk assessment, the operator of the facility shall provide notice to all exposed persons regarding the results of the health risk assessment prepared pursuant to Section 44361 if, in the judgment of the district, the health risk assessment indicates there is a significant health risk associated with emissions from the facility. If notice is required under this subdivision, the notice shall include all information concerning significant health risks attributed to the specific facility for which notice is required. Any notice shall be made in accordance with procedures specified by the district (California Health and Safety Code, Section 44362 [b]).” Based on information provided by the California Air Resources Board (CARB), the District has established the following Notification Levels (CARB 2021):
• An incremental cancer risk increase greater than or equal to ten in one million (i.e., 1 x 10-5); • A chronic or acute, non-cancer hazard index (HI) greater than or equal to 1.

The methods developed by the State of California to meet the goals of AB2588 have been adopted by the District to expedite review of HRAs, allow comparisons between facilities using a consistent methodology, and to ensure implementation of the Office of Environmental Health Hazard Assessment (OEHHA) Air Toxics Hot Spots Program Guidance Manual for Preparation of Health Risk Assessments (“OEHHA Hot Spots Guidance,” California Environmental Protection Agency [Cal/EPA] 2015). The risks calculated using the OEHHA Hot Spots Guidance (Cal/EPA 2015) methods are reflective of upper-bound 43 Air Toxics Hot Spots (AB 2588) Health Risk Assessment Report Humboldt Sawmill Company—Scotia, California
2125002.020
June 15, 2026 iv landauinc.com
estimates of risk and are likely not representations of the actual risk incurred by exposures attributable to the Facility. Rather, risk estimates predicted within the AB2588 framework are intended to provide a consistent point of comparison for significance or Notification Levels established by each District within the State.

An HRA prepared under the AB2588 framework is comprised of three main components:
1) An inventory of TACs emitted from the Facility,
2) Air dispersion modeling that incorporates the emission inventory, and 3) A health risk analysis of the modeling results.

The District’s Guidelines for Preparation and Submission of Health Risk Assessments (NCUAQMD 2025) was also used to prepare this HRA. The methods used to complete the HRA that Landau prepared for HSC are briefly outlined below and are discussed in detail throughout this report.

Facility Emissions
The Facility is a lumber manufacturing facility that produces lumber products and generates electricity.

Lumber is produced from received logs in the sawmill, which are then dried in the lumber dry kilns. A planer is used to surface the dried lumber and a trimmer is used to cut the lumber to marketable lengths. Collected wood residues from the sawing and planing processes fuel the three biomass-fired boilers at the Facility to produce steam which heats the kilns and powers turbines and generators to produce electricity. Particulate matter in the boiler exhaust is reduced by cyclones and electrostatic precipitators. Wet cooling towers are used to dissipate excess heat from equipment and process streams, and are supplied with recirculating water that is treated with appropriate chemical additives.

An on-site diesel-fired emergency generator provides emergency power as needed. Detailed information about TAC emission units and emitted TACs including calculated maximum 1-hour (hr) emission rates and annual average emission rates are included in Appendix A.

Air Dispersion Modeling
Air dispersion modeling was conducted using the American Meteorological Society/Environmental Protection Agency (EPA) Regulatory Model (AERMOD version 24142), which is the EPA recommended air dispersion model. Modeling was prepared using a network of receptors located in alignment with OEHHA Hot Spots Guidance and meteorological data collected at the Arcata Airport during years 2017 through 2021 which was pre-processed by CARB.

Health Risk Assessment
The purpose of the HRA is to estimate the potential off-site human health impacts attributable to emissions from Facility operations and compare them with the District Notification Levels.

HSC submitted an Emission Inventory Report (EIR) of actual 2022 Facility emissions to the District in October of 2025. The District performed a prioritization following the California Air Pollution Control Officers Association (CAPCOA) Facility Prioritization guidelines. The result of the prioritization indicated 44 Air Toxics Hot Spots (AB 2588) Health Risk Assessment Report Humboldt Sawmill Company—Scotia, California
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June 15, 2026 v landauinc.com
that the Facility was designated as a high priority facility. The actual 2022 Facility emissions submitted to the District with the EIR were used for the dispersion modeling, the results of which were used to calculate HIs and cancer risk increases for the HRA.

The methods and results of the 2022 HRA are presented in this document. Cancer risk increases and noncancer HI were calculated using the Cal/EPA Hotspots Analysis and Reporting Program Version 2 (HARP2) Air Dispersion Modeling and Risk Tool (ADMRT) (version 22118, CARB 2022). HARP2 is a software program designed to assist with the implementation of health risk assessment guideline recommendations by joining air dispersion modeling with the risk assessment techniques identified in the OEHHA Air Toxics Hot Spots Program Guidance Manual for Preparation of Health Risk Assessment (Cal/EPA 2015).

Results Summary
Potentially exposed populations evaluated in the HRA include residents, off-site workers, and sensitive receptors. Five sensitive receptors were identified within the modeling domain, including schools, a childcare facility, a hospital, and a licensed care facility. The maximum sensitive receptor was identified as Stanwood Murphy Elementary School, located approximately 230 meters northeast of the Facility boundary. The point of maximum impact (PMI) was located west of the Facility in timberland where people do not currently live or work; therefore, risks at that location are conservative screening estimates rather than actual exposure estimates for an occupied receptor.

Estimated cancer risk increases were 4.3 in one million at the maximum exposed individual resident (MEIR), 0.17 in one million at the maximum exposed individual worker (MEIW), and 1.4 in one million at the maximum sensitive receptor, all of which are less than the District notification threshold, which is 10 in one million. The estimated cancer risk increase at the PMI was 29 in one million; however, because this location is in unoccupied timberland owned by HSC and was evaluated using conservative residential exposure assumptions, it represents an upper-bound screening result rather than an actual community exposure point. As discussed in Section 5, the modeled cancer risk increases are intentionally health-protective and are likely overestimates of actual risk increases.

Noncancer HIs were also less than the District notification thresholds for all occupied receptor types, except for the Acute HI at the MEIR. Acute HIs were 1.7 at the MEIR, 0.24 at the MEIW, and 0.23 at the sensitive receptor. The Acute HI at the MEIR is greater than the District notification threshold, which is

1.0. The MEIR is located in an area of Rio Dell that is zoned rural residential; however, review of aerial photographs that include the parcel where the MEIR is located indicates that there may not be a residence on that parcel. Chronic HIs were 0.15 at the MEIR, 0.072 at the MEIW, and 0.045 at the maximum sensitive receptor. The 8-hour chronic HIs were 0.0088 at the MEIR, 0.0062 at the MEIW,

0.0030 at the sensitive receptor. At the PMI, the chronic HI was 1.1, the 8-hour chronic HI was 0.070 and the acute HI was 3.8; however, as with the cancer risk increase result outlined above, the PMI does not represent an occupied receptor and is based on conservative residential assumptions. The maximally affected target organ for annual chronic impacts, 8-hour chronic impacts, and acute impacts were respiratory, central nervous system, and eye irritation, respectively. Consistent with the uncertainty 45 Air Toxics Hot Spots (AB 2588) Health Risk Assessment Report Humboldt Sawmill Company—Scotia, California
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June 15, 2026 vi landauinc.com
discussion in Section 5, these hazard estimates should be interpreted as upper-bound values that are expected to be greater than actual exposures and risks.

The TACs that contribute most to potential health impacts vary somewhat by receptor, but the principal drivers are consistent across the assessment. Cancer risk increase is driven primarily by arsenic, benzene, acetaldehyde, chromium(VI), and cobalt. Chronic noncancer hazard is dominated largely by chlorine, with smaller contributions from nickel, acrolein, and arsenic. Acute hazard is driven primarily by acrolein, followed by formaldehyde and acetaldehyde. The sensitive subpopulations of greatest concern include schoolchildren, childcare attendees, hospital occupants, and residents of licensed care facilities, although modeled risks at these receptors remained less than applicable notification thresholds. Table 1 provides a brief description of the impacts of the predominant emitted TACs as noted in the OEHHA Technical Support Document for the Derivation of Noncancer Reference Exposure Levels and 6 RELs, Appendix B, Table B.1.1 (OEHHA 2008).

Table 1. Predominant Pollutant Impacts
Substance Chronic Impacts 8-hour Chronic Impacts Acute Impacts Acetaldehyde Respiratory system Respiratory system Eyes; Respiratory system (sensory irritation)
Acrolein Respiratory system Respiratory system Eyes; Respiratory system (sensory irritation)
Arsenic Inhalation and Oral:

Development; cardiovascular
system; nervous system;
respiratory system; skin
Development; cardiovascular
system; nervous system;
respiratory system; skin
Development; cardiovascular
system; nervous system
Benzene Hematologic and nervous
systems; development
-- Reproductive/
development; immune
system; hematologic system
Chlorine Respiratory system -- Respiratory system; eyes Chromium(VI) Inhalation: Respiratory
system
Oral: Hematologic system
-- --
Cobalta Respiratory system,
hematological system,
endocrine system
Respiratory system,
Cardiovascular system
Respiratory System
Formaldehyde Respiratory system Respiratory system Eyes (sensory irritation) Manganese Nervous system Nervous system --
Nickel Inhalation: Respiratory
system; hematologic system
Oral: Development
Respiratory system, immune
system
Immune system
Note:
46 Air Toxics Hot Spots (AB 2588) Health Risk Assessment Report Humboldt Sawmill Company—Scotia, California
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June 15, 2026 vii landauinc.com
a. Appendix B of the OEHHA Technical Support Document does not include pathway impacts from cobalt exposure. Pathway impacts for cobalt were obtained from the Agency for Toxic Substances and Disease Registry (ATSDR 2024).

The estimated population cancer burden was calculated by multiplying the cancer risk in a census tract by the number of people who live in the census tract. Using a conservative screening assumption that the census tract population experiences exposures equivalent to the excess cancer risk attributable to the Facility at the PMI, the calculated cancer burden was 0.13, which is less than the District Notification Level of one. This estimate is intentionally health-protective and likely overstates actual community exposure because it assumes uniform exposure at the greatest modeled off-site impact location.

Overall, the HRA indicates that TAC emissions attributable to the Facility, as represented by the 2022 emission inventory, do not pose significant health risks at locations where people live, work, attend school, or receive care. As described in Section 5, uncertainty in this assessment is associated with emission estimation, air dispersion modeling, exposure assumptions, toxicity values, and risk calculations; however, the analyses intentionally apply conservative assumptions throughout so that modeled results represent estimated upper-bound impacts rather than likely actual impacts.

Accordingly, actual risk increases are expected to be less than those presented here. Based on the modeled results, cancer risk increases and noncancer HIs at the MEIR, MEIW, and sensitive receptor locations do not exceed District notification thresholds; therefore, the modeled occupied receptor impacts attributable to the Facility do not trigger District notification requirements. The Acute HI at the MEIR is greater than the District notification threshold, which is 1.0. This receptor is located in an area of Rio Dell that is zoned rural residential; however, review of aerial photographs that include the parcel where the MEIR is located indicates that there may not be a residence on that parcel, and therefore would not require notification.

Note:

This draft report is subject to review and revision by the North Coast Unified Air Quality Management District and the California Office of Environmental Health Hazard Assessment.

See https://redwoodenergy.org/about/energy-sources/ under the "Local Biomass Energy" heading for a link to the full draft report.
47 This page
intentionally
left blank.
48 Review of Annual Reporting
Materials from Humboldt Sawmill
Company
Presentation to Board of Directors
September 24, 2026
Topics
• Refresher on RCEA’s power purchase agreement and
memorandum of understanding with Humboldt Sawmill Company • Materials provided by HSC this year per MOU
• Review by Biomass Technical Advisory Group
• Review by Community Advisory Committee
• Visualizations of the data provided by HSC
Power Purchase Agreement with Humboldt Sawmill Company
RCEA’s power purchase agreement with HSC lists events of default, including “Seller’s failure to operate the Project in compliance with all applicable Laws as determined by the Governmental Authority charged with implementation and/or enforcement of the specific Law at issue.”
RCEA has consulted repeatedly in recent years with the North Coast Unified Air Quality Management District, who have at times issued notices of violation to HSC. The Air District notes the corrective actions HSC has taken to remediate these violations.

RCEA’s general counsel has determined, and recently reiterated, that such intermittent violations do not rise to the level of an event of default on the PPA as described above.

Memorandum of Agreement (2021)
The MOU was developed in response to RCEA Board’s desire to be kept informed on the HSC plant’s performance, and on the owners’ exploration of alternative uses for their biomass fuel.

The MOU’s purpose is not to terminate or otherwise override the terms of the PPA.

As the MOU states: “This MOU does not and is not intended to supersede, replace, or subordinate any provisions, representations, covenants, rights, or obligations in the PPA.”
While the MOU does not allow for early termination of the biomass PPA, it could help form a pathway for alternative use of the biomass plant’s feedstock material once the current PPA’s term expires.

Materials Provided by Humboldt Sawmill Company
• Completed RCEA-supplied reporting template including data on fuel use and sources, electric production, and emissions • Monthly cogen reports to NCUAQMD for Jan-Dec 2025, including emissions and opacity data
• Quarterly cylinder gas and opacity audits
• Throughput report showing monthly totals of steam produced, biomass and diesel fuel use, and days of operation for each of the plants three boilers
Additional Information and Materials for Board Review
• HSC reported that they received no new notices of violation from the Air District in the past reporting year. This was the first reporting year since the MOU reporting cycle began in 2021 that HSC has had no notices of violation.
• RCEA requested and received from the Air District a draft Health Risk Assessment (HRA) Report prepared for HSC at the Air District’s direction by Landau Associates. The assessment, which was conducted per the Air Toxics “Hot Spots” Information and Assessment Act of 1987 (Assembly Bill 2588) and delivered to the Air District on June 15, 2026, modeled and quantified impacts of HSC plant emissions on health of populations near the plant. The draft report found that cancer risks fall below the Air District’s notification or remediation thresholds. The draft report is subject to review and revision by the Air District and the State-level Office of Environmental Health Hazard Assessment before receiving final approval.
• The US EPA issued an order denying petition dated May 5, 2026 in response to the January 1, 2025 petition from the Environmental Protection Information Center and the Humboldt Coalition for Clean Energy that staff reported to the CAC last year. That petition had asked the EPA to object to the Title V operating permit issued to HSC by the Air District.

Public Access to HSC Reporting Materials
RCEA has made the reporting materials described on the
preceding slides available
at https://redwoodenergy.org/about/energy-sources/ under the “Local Biomass Energy” subheading
Annual Meeting of HSC and RCEA, and BTAG follow-up
• HSC and RCEA staff met on June 16, 2026 to review HSC's reporting materials • Staff were unable to convene a meeting of the Biomass Technical Advisory Group (BTAG) this year to review the HSC materials, due to very limited availability of BTAG members during the summer season following release of the materials.
• Staff instead sought written feedback from BTAG members on the HSC materials but received minimal response.
• Alternative biomass uses: HSC reported that they continue to evaluate potential for using biomass in alternative power generation or hydrogen production facilities. They reported that project economics continue to be a challenge and did not have any new progress on project development to report.

Discussion by Community Advisory Committee
• Staff presented the materials provided by or regarding HSC to the CAC at their Sept. 8 meeting • Committee members asked about the relatively high level of emissions per unit of energy produced at the facility
• CAC members expressed concern about particulate matter from the facility, given close proximity to school
• Members also expressed concern about the minimal response from the Biomass Technical Advisory Committee
• A member noted that CAC comments and requests for information over the last several years in the framework of the MOU have improved HSC's public transparency Visualizations of Data Provided by
Humboldt Sawmill Company

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Diesel Use (Gallons)
HSC reports plant
improvements
including capping
off unused steam
line have resulted
in reduced diesel
fuel use

THANK YOU

Staff Report
Agenda Item # 11.2
Information
Agenda Date September 24, 2026
To Board of Directors
Prepared by Eileen Verbeck, Deputy Executive Director
Subject Grid Resilience Innovation Partnership (GRIP) Program Funds for Tribal Energy Resilience and Sovereignty Project Final Award Execution and Staffing Background
In December 2024, the RCEA Board authorized RCEA to execute a conditional award with the Department of Energy (DOE) for the Grid Resilience Innovation Partnership (GRIP) Program Funds for Tribal Energy Resilience and Sovereignty Project. The conditional award funds the Tribal Energy Resilience and Sovereignty Project (TERAS), which proposes to develop tribally owned and operated microgrids.

Originally, four Tribes were involved in the TERAS project including the Hoopa Valley Tribe, Yurok Tribe, Karuk Tribe, and Blue Lake Rancheria Tribe (BLR). Since the submission of the original application, the Karuk Tribe has withdrawn from the project.

As a step on the path towards a transformed regional energy system, the Parties are embarking on a project to support resilience within the Hoopa Valley Reservation and the Upriver portion of the Yurok Reservation. These areas face significant barriers to decarbonization and clean energy deployment and suffer from very low electricity reliability. These areas are all served by the Pacific Gas and Electric (PG&E) on the Hoopa 1101 distribution circuit ("Hoopa 1101 Circuit”).

BLR is not served by the Hoopa 1101 Circuit but rather has an existing microgrid and seeks additions to its microgrid capabilities. BLR's existing behind-the-meter community microgrid will be expanded to interconnect three existing facility-scale microgrids that are geographically distributed across the reservation inside their main campus microgrid in a nested configuration. The new nested microgrid configuration at BLR will act as a proving ground. It will allow the team to test and demonstrate the nested microgrid configuration, controls, and protection schemes that will also be implemented on the Hoopa 1101 Circuit. In addition, the upgrades at BLR will create a highly effective hands-on learning environment to support TERAS Tribal partners and others in understanding microgrids, advanced distribution management systems, cybersecurity, and real-time operational roles and responsibilities.

The microgrids on the Hoopa 1101 Circuit will also allow for energy market participation during “blue sky” conditions, and stand-alone Tribal resilience during disasters or planned power shut-off events. These systems, built and operated by Tribes in collaboration with local partners, will deliver technology innovations, direct and sustained community benefits, and valuable business model advances. 49

The Schatz Energy Research Center will provide technical assistance to support the TERAS Project.

RCEA was asked to step in as the lead applicant for the TERAS Project to assist with the administration of the grant funds. RCEA will also contribute to the required 50% GRIP Project cost share requirement with an awarded $6,000,000 California Energy Commission (CEC) match grant.

Summary
The Department of Energy has notified RCEA staff that they anticipate executing the GRIP program final award no later than September 30, 2026. Staff request Board authorization to execute the final award and associated terms and conditions.

In July 2024, the Department of Energy notified RCEA that the TERAS project GD-0000967 was selected to begin award negotiations and was proposed to be fully funded for a total of $87,629,455. RCEA executed a conditional award in January 2025 in anticipation of finalizing the award within 120 days.

However, due to federal administration changes, the finalization of the award was paused.

In February 2026, the Department of Energy reestablished negotiations with RCEA to finalize the award.

At that time RCEA was notified that the solar and community benefits plan portions of the project were not in alignment with the current Administrations priorities, and the partners were given the opportunity to re-scope the project to remove those components. Additionally, one of the Tribal partners, the Karuk Tribe, had withdrawn from the TERAS project. The TERAS team made the decision to de-scope the project to remove the Karuk portion of the project and remove expenditures associated with solar and the community benefit plan. The updated federal award amount proposed to be fully funded is $65,541,555 with a 1:1 cost share requirement for a total project cost of $132,092,000.

The federalized portion of the project will include the following technologies:
• Battery Energy Storage Systems
• Small Hydroelectric Generation Facility
• Long Duration Energy Storage Battery Systems
• Emergency Generators (back-up systems)
The Tribes may continue to use solar technology for generation, but the associated costs will not be included in the Department of Energy federalized award.

RCEA TERAS Staffing
The TERAS project budget includes funding for RCEA staff to administer the award for the duration of the project. When the Board of Directors approved RCEA’s current fiscal year budget, all vacant positions were frozen, so existing staff have been completing all the necessary pre-award negotiation work. Once the award is finalized, TERAS project funding will be available and allow the unfreezing of up to 1.5 full-time equivalent positions to provide additional capacity necessary to move into project implementation. At this time, staff recommends the Board authorize unfreezing the vacant Contracts and Grants Manager position to help with TERAS Project implementation. 50

Equity Impacts
RCEA’s engagement in the TERAS Project furthers the following RCEA Racial Justice Plan initiatives:

External Partnerships and Programs

1. Tribal Engagement:
b) RCEA staff will continue and expand efforts to identify opportunities to collaborate with local Tribes as partners on sustainable energy initiatives.

3. Energy justice in power procurement and energy resource development:
a) RCEA staff will incorporate energy justice best practices and affordability into renewable development and power purchase solicitations and resource planning. b) RCEA will continue to include project location and community benefit in its evaluation criteria for power solicitations, to contract for projects that benefit racially diverse communities and to avoid projects that are detrimental to those communities.

Alignment with RCEA’s Strategic Plan
The TERAS Project supports the following RePower Goals:
• 1.1.3 Support Energy-sector Workforce Development.
• 2.1.7 Support and Deploy Microgrids.
• 4.1.4 Maximize Renewable Energy Content of RCEA’s CCE Program. • 4.1.7.3 Provide Feed-In-Tariff Power Procurement Program for Small Generators. • 4.1.8.2 Procure Local Solar Energy.
• 4.3.4 Provide Match Funding for State, Federal, and Foundation Energy Grants.

Financial Impact
The TERAS project budget includes funding for RCEA to implement its role as the prime award recipient and procure federal award compliance oversight services, including staff positions for the duration of the project (6 years). RCEA’s portion of the required cost-share (match) will be funded through the above-referenced CEC grant.

The project budget also includes labor costs associated with the pre-award negotiation process from January 2025 through September 2026, which will be reimbursed shortly after the award is finalized and was included as anticipated revenue in the current RCEA adopted budget. Staff may propose adjustments to the current RCEA budget related to the TERAS funding after the award is finalized.

Staff Recommendation
Authorize RCEA Executive Director to execute the Department of Energy Grid Resilience Innovation Partnership (GRIP) Program Funds for Tribal Energy Resilience and Sovereignty Project GD-0000967 Final Award and Unfreeze the Contracts and Grants Manager Upon Execution of Final Award. 51

Attachments
None.
52

Staff Report
Agenda Item # 12.1
Information
Agenda Date September 24, 2024
To Board of Directors
Prepared by Elizabeth Burks, Executive Director
Subject
Approval of Memorandum of Understanding Establishing RCEA as the Host Agency for the Regional Climate Committee and Climate Program Manager Position to Coordinate the Implementation of the Regional Climate Action Plan Summary
The Regional Climate Action Plan (RCAP) was first adopted by the County of Humboldt in December 2025, with several other jurisdictions adopting it in the following months. A Regional Climate Committee and Regional Climate Program Manager position are cornerstone strategies of the RCAP and essential to successful implementation.

Since early 2026 RCEA has been coordinating with the Regional Climate Action Plan working group consisting of staff from the County, the seven incorporated cities, and Humboldt County Association of Governments (HCAOG), Humboldt Transit Authority (HTA), and Humboldt Waste Management Authority (HWMA), to develop a Memorandum of Understanding (MOU) that would allow RCEA to host the Regional Climate Committee and the Regional Climate Manager position.

The purposes of this MOU are to collaborate in establishing an operational framework for the Regional Climate Committee and developing a sustainable funding mechanism for the Regional Climate Committee and the Climate Program Manager. After RCEA adoption, the MOU would become effective after adoption by a sufficient number of Municipal Jurisdictions whose respective populations together represent at least 85% of the overall population of Humboldt County. This MOU shall terminate on December 31, 2030, unless extended by mutual written agreement of the Parties.

Regional Climate Committee
The MOU specifies that the RCEA Board along with an elected representative from the boards of HTA, HCAOG, and HWMA would act as the Regional Climate Committee. Each official appointed to the Regional Climate Committee is charged with addressing climate change at a coordinated regional level to implement the RCAP.

Logistically, Regional Climate Committee meetings are intended to occur during regularly scheduled RCEA Board meetings. When there are RCAP-specific items to address, the meeting would proceed as follows:

1. The RCEA Board would adjourn its regular meeting.
53

2. The Regional Climate Committee would convene, including representatives from HTA, HCAOG, and HWMA.

3. The Regional Climate Committee would conduct its business and then adjourn.

4. The RCEA Board would reconvene and continue its regular meeting.

For decisions involving grants, contracts, or other agreements where RCEA is the prime applicant or party, the RCEA Board would serve as the final decision maker.

This meeting structure is similar to that of the County’s Airport Land Use Commission and HCAOG’s Policy Advisory Committee.

Regional Climate Program Manager and Funding Contributions The RCAP calls for the creation of a Climate Program Manager (“Manager” or “Program Manager”) to lead the coordination efforts of the Committee, and to coordinate with staff of the participating jurisdictions and agencies to undertake the work of the Committee. The coordination will take many forms including convening a staff level Technical Advisory Committee that will advise the Regional Climate Committee.

Under the RCAP, the Program Manager is intended to represent a larger staff need to fulfill the mission of the Committee to obtain funding to support several staff in implementing and tracking the RCAP.

Additionally, the RCAP charges the Manager with developing annual progress reports on RCAP implementation for City Councils and County Supervisors to measure progress and establish accountability in achieving RCAP emissions reduction goals.

This position is funded with contributions from participating jurisdictions for the term of the MOU.

Contributions from jurisdictions will also be sufficient to cover the costs of RCAP implementation measure tracking software. Contributions consistent with Exhibit A to the MOU will be collected from each participating jurisdiction and used only for Climate Action Plan purposes such as the Climate Program Manager position, software, consultant services, or grant program match. The Regional Climate Committee will approve the use of these expenses.

RCEA Commitments
This MOU commits RCEA to hosting the Regional Climate Committee and the Climate Program Manager Position for the term of the MOU. It also commits RCEA to providing staff resources and incidental costs totaling approximately $145,000 annually for the term of the MOU. These costs have been included in the current fiscal year budget and would need to be continued in future fiscal years during the term of the MOU.

Staff resources will include participation in RCAP activities by the Executive Director, Director of Engagement and Regional Climate Planning, Community Strategies Team, and Board Clerk.

Memorandum of Understanding (MOU) Process
After adoption by RCEA the MOU will be considered by each party to the MOU. Once the Municipal Jurisdictions whose respective populations together represent at least 85% of the overall population of Humboldt County sign on, the MOU would become effective. 54

RCEA has already received confirmation from the County of Humboldt, City of Eureka and City of Arcata, that they intend to take the MOU to their decision makers in October. Others are likely to follow in future months. The Regional Climate Committee could possibly convene as early as November.

Background
The RCAP is designed to reduce countywide GHG emissions to 40% below 1990 levels by 2030, consistent with Senate Bill (SB) 32, and to make substantial progress toward carbon neutrality by 2045, consistent with Assembly Bill (AB) 1279. The RCAP is meant to function as a "playbook" that local agencies can use to prioritize actions, coordinate projects, and track progress over time, recognizing that implementation will be phased and dependent on available capacity and funding.

The initial drafting of a Climate Action Plan (CAP) began in 2019 through collaboration with the County, all incorporated cities (Arcata, Blue Lake, Eureka, Ferndale, Fortuna, Rio Dell, and Trinidad), and RCEA.

These entities entered into a Memorandum of Understanding committing to develop a shared regional climate action plan to reduce GHG emissions on a coordinated, countywide basis. The group worked in coordination with regional agencies including the Humboldt County Association of Governments, Humboldt Transit Authority, and Humboldt Waste Management Authority.

The Final RCAP was adopted by the Humboldt County Board of Supervisors in December 2025, with adoption by the Cities of Arcata, Eureka, Ferndale, Fortuna, Rio Dell occurring in 2026.

Development of the RCAP strategy showed that the region had greater chances to accomplish goals and achieve GHG reductions when working as a region rather than a collection of individual jurisdictions.

This approach allows for a consolidation of resources and avoids jurisdictions competing for the same resources, which is a change from prior drafts of the CAP. The RCAP is designed with the understanding that meaningful climate action will take sustained effort, long-term coordination, and adequate resources.

Given the region’s limited staffing and funding capacity, many higher-cost or complex strategies will rely on extended collaboration and, in many cases, outside funding and partnerships.

In 2025, members of the working group asked RCEA leadership to consider hosting the Regional Climate Committee and the Climate Program Manager position. The RCEA Board reviewed this potential role beginning in January 2026 and continuing through adoption of the Fiscal Year 2026-2027 budget. During that process, the Board supported RCEA serving as the host agency for both the Regional Climate Committee and the Climate Program Manager.

Equity Impacts
Any RCAP implementation activities will be done in the context of RCEA’s Racial Justice Plan initiatives.

Alignment with RCEA’s Strategic Plan
Approval of this MOU supports RCEA's work to further these RePower Humboldt Regional Energy Planning & Coordination strategies, among others, listed in the agency's strategic plan:
• 1.4.3 Assist with Climate Action Planning
Work with local jurisdictions to regularly complete greenhouse gas inventories, set greenhouse gas reduction targets, and develop climate action plans 55

• 1.4.4 Support Countywide Strategic Energy Planning
Coordinate an effective energy strategy based on self-sufficiency, development of renewable energy resources, energy conservation, and electrification that is actively implemented countywide through Climate Action Plans, General Plans and the Redwood Coast Energy Authority’s RePower Humboldt plan.

Financial Impact
The cost of entering this MOU consists of staff resources and incidental costs totaling approximately $145,000 annually for the term of the MOU. This is consistent with budgeted amounts in the current adopted budget. These costs will also need to be budgeted in future fiscal years during the term of the MOU. The cost of the Climate Program Manager position is covered through the contributions from the Municipal Jurisdictions
Staff Recommendation
Approve the Memorandum of Understanding Establishing RCEA as the host agency for the Regional Climate Committee and Climate Program Manager Position to coordinate the implementation of the Regional Climate Action Plan.

Attachments

1. Regional Climate Action Plan Memorandum of Understanding

2. Exhibit A Funding Commitments
56 ---------- September 18, 2026 DRAFT ---------

MEMORANDUM OF UNDERSTANDING BETWEEN

RCAP LOCAL AGENCIES AND
PARTNER JPA’S

REGARDING ESTABLISHMENT OF THE REGIONAL CLIMATE COMMITTEE AND

CLIMATE PROGRAM MANAGER
This Memorandum of Understanding (“MOU”) is entered into and made effective as of _________, 2026 (“Effective Date”) by and among some or all of the local agencies identified below. Each of the agencies referenced below is referred to herein individually as an “Agency” and collectively as the “Agencies.” Each of the signatories to this Agreement is referred to herein as a “Party” and collectively as the “Parties”.

Municipal Jurisdictions:

City of Arcata (“Arcata”)
City of Blue Lake (“Blue Lake”)
City of Eureka (“Eureka”)
City of Ferndale (“Ferndale”)
City of Fortuna (“Fortuna”)
City of Rio Dell (“Rio Dell”)
City of Trinidad (“Trinidad”)
County of Humboldt (“County”)
Joint Powers Authorities (JPAs):

Humboldt County Association of Governments (“HCAOG”)
Humboldt County Transit Authority (“HTA”)
Humboldt Waste Management Authority (“HWMA”)
Redwood Coast Energy Authority (“RCEA”)

BACKGROUND RECITALS AND SHARED GOALS
A. The Agencies have collaborated in development of a comprehensive Regional Climate Action Plan (“RCAP”) to address greenhouse gas (“GHG”) emissions generated within the Humboldt County region. The RCAP and final environmental impact report were completed by the County and adopted by its Board of Supervisors on December 16th, 2025, and adopted by the other Municipal Jurisdictions on the following dates:

Arcata: May 6, 2026
Blue Lake:

Eureka: February 3, 2026
Ferndale: September 16, 2026
Fortuna: May 18, 2026
Rio Dell: March 17, 2026
Trinidad:

B. The RCAP establishes a regional goal to reduce GHG emissions 40 percent by 2030 in line with Statewide targets of Senate Bill 32 and provides measures and actions to achieve this goal. In addition, the RCAP establishes a longer-term regional goal of achieving carbon neutrality by 2045, consistent with the Statewide goals of Assembly Bill 1279; and quantitative efficiency thresholds for use in evaluating whether the GHG emissions of an individual plan or project would result in a potentially significant environmental impact under the California Environmental Quality Act (“CEQA”) for plans or projects with pre-2030 buildout or initial operation years (“GHG Emissions 57 ---------- September 18, 2026 DRAFT ---------

Thresholds”). The overall purpose of the RCAP and CEQA GHG Emissions Thresholds is to prepare, adopt, and implement a qualified GHG reduction plan that may be utilized for mitigating and tracking Countywide GHG emissions as well as for streamlining CEQA GHG analyses for future projects within the Humboldt County region that are required to undergo CEQA review.

C. A cornerstone strategy of the RCAP is the establishment of a coalition between jurisdictions and key organizations to guide a regional approach to climate-related challenges through coordinated efforts.

Based on this, creation of a Regional Climate Committee (“Committee”) comprised of elected officials from each of the Municipal Jurisdictions and JPA’s to be responsible for implementing RCAP measures and actions is the first RCAP strategy to be implemented. The purpose of the Committee is to foster collaboration and coordination among the region to address climate-related challenges and implement effective climate action strategies by leveraging collective expertise, resources, and efficiencies to tackle climate change at a regional level. The Committee will support RCAP implementation through information sharing, coordination of RCAP efforts, development of joint initiatives to reduce GHG emissions, support and pursue funding, and promote sustainable development practices. Additionally, the Committee will develop and provide models, pilot programs, and template policies or ordinances that enable each jurisdiction in the region to implement uniform changes and facilitate local communities in making the necessary structural adjustments to reduce GHG emissions.

D. The RCAP also calls for the creation of a Climate Program Manager (“Manager” or “Program Manager”) to lead the coordination efforts of the Committee, and to coordinate with staff of the participating jurisdictions and agencies to undertake the work of the Committee. Under the RCAP, the Program Manager is intended to represent a larger staff need to fulfill the mission of the Committee to obtain funding to support several staff in implementing and tracking the RCAP.

Additionally, the RCAP charges the Manager with developing annual progress reports on RCAP implementation for City Councils and County Supervisors to measure progress and establish accountability in achieving RCAP emissions reduction goals.

E. RCEA has agreed to host the Committee and the Program Manager and to commit staff resources and incidental costs totaling approximately $145,000 per year.

F. This MOU seeks to establish the framework for establishing the Committee and funding the Regional Climate Program Manager. NOW THEREFORE, based on these Background Recitals and Shared Goals, the Parties enter into the following Memorandum of Understanding:

1. Purpose. The purposes of this MOU are to collaborate in the following endeavors:
i. Establishing an operational framework for the Regional Climate Committee; ii. Developing a sustainable funding mechanism for the Regional Climate Committee and the Climate Program Manager.

2. Host Agency. To facilitate the successful outcome of the RCAP, RCEA agrees to host the Climate Program Manager (“Manager”), and provide administrative support to the Regional Climate Committee (“Committee”) and advisory committees created by the Committee. The Manager shall be solely an employee or independent contractor of RCEA and no other Party to this MOU when acting in the capacity of Regional Climate Manager and shall not be entitled to any employment benefits from any other agency. The RCEA Board shall serve as the final decision maker for any RCAP grants, contracts, or other agreements where RCEA is the prime applicant or party to the contract or agreement.
58 ---------- September 18, 2026 DRAFT ---------

3. Regional Climate Committee. The Committee will be responsible for implementing RCAP measures and actions. The Committee structure shall be as follows:
a. Committee Membership. The RCEA Board of Directors, which includes representation from the County and each City as well Tribal nations, together with an elected official appointed from and by each of the Boards of Directors of Humboldt Waste Management Authority, Humboldt Transit Authority and Humboldt County Association of Governments shall be the acting Regional Climate Committee. Each official appointed to the Regional Climate Committee (a “Member”, or “Committee Member”) is charged with addressing climate change at a coordinated regional level to implement the RCAP.

b. Quorum. A majority of the total number of Committee Members shall constitute a quorum for conducting business.
c. Voting. Each Committee Member shall have one equal vote. Alternate representatives may only vote in the absence of the primary representative from that Agency. Completion of any action of the Committee shall require the affirmative vote of the Members present.

4. Committee Operational Rules, Bylaws. The Committee may establish by unanimous vote any additional, non-conflicting operational protocols, guidelines, or procedures as necessary to facilitate its operations (the “Bylaws”). The Committee shall function in accordance with this MOU, any Bylaws, and applicable law. Bylaws shall be amended only upon approval by a unanimous vote of the Committee.

5. Regional Climate Program Manager.
a. Sustainable Funding of Position. The Manager is a cornerstone strategy of the RCAP.

Establishing sustainable funding for the Manager shall be a priority of the Committee.

Funding will occur as direct annual financial contributions from the Municipal Jurisdictions for the term of this MOU. During the term of this MOU, the Regional Climate Committee will develop a long-term funding strategy for RCAP implementation and sustainable funding for the Manager position that may include direct annual contributions, grants, or other available sources.
b. Primary Duties. Using the RCAP as a strategic planning document the Manager will generally:
i. Plan, organize, oversee, coordinate, and manage the RCAP programs, projects, and activities including facilitating RCAP Committee activities; ii. Identify and pursue external funding opportunities; iii. Serve as administrative manager of multi-agency programs; iv. Serve as a liaison and foster cooperative working relationships with a variety of internal and external stakeholders, partners, and contracted service providers; v. Coordinate with staff of the participating jurisdictions and agencies to undertake the work directed by the Committee.
vi. Deliver annual progress reports to City Councils and the County Board of Supervisors to measure progress and establish accountability in achieving RCAP emissions reduction goals
59 ---------- September 18, 2026 DRAFT ---------

c. Interaction with Committee. The Manager will provide staff support to the Committee including ensuring compliance with the California Ralph M. Brown Act and other applicable laws.

6. Regional Climate Technical Advisory Committee. Each Agency may choose to designate staff to participate in a Regional Climate Technical Advisory Committee (“TAC”). The purpose of the TAC is to provide input to the Manager and Committee.

7. Shared Funding Commitments to Support RCAP Implementation and the Climate Program Manager.
a. Principles of Shared Commitment to Sustainably Fund the Regional Climate Program Manager:
i. The Regional Climate Action Plan calls for the creation of a regional Climate Program Manager position to lead and coordinate the implementation of the Regional Climate Action Plan;
ii. A Regional Climate Program Manager position would provide for regional efficiencies and cost-savings in completing the work outlined in the Regional Climate Action Plan;
iii. The successful region-wide implementation of the RCAP is a shared responsibility;
iv. Shared financial responsibility is most equitably determined using the total population of the County and the percentage residing within each Municipal Jurisdiction.
v. RCEA created a Regional Climate Program Manager position within RCEA with the understanding that Municipal Jurisdiction contributions would be required to sustainably fund the position.
b. Municipal Jurisdiction Commitments. Municipal Jurisdictions agree to contribute funds to support RCAP implementation and the Program Manager in the amounts set out in Exhibit A, Funding Commitments.
c. Funding Commitments. Proportional funding contributions by each Municipal Jurisdiction prorated by population are set out in Exhibit A, Funding Commitments.

8. Annual Budget. RCEA will separately account for direct funding contributions, and will develop an annual RCAP implementation budget based on direct funding contributions for annual review and approval by the Committee. The budget shall be applied to Program Manager salary costs and direct RCAP implementation expenses, such as vendors, consultants, climate tracking software, and similar expenses. Any budgeted funds unspent at the end of a fiscal year will be carried over to following years. The Regional Climate Committee may revise the annual budget as needed.

9. MOU Term. This MOU shall terminate on December 31, 2030, unless extended by mutual written agreement of the Parties.
60 ---------- September 18, 2026 DRAFT ---------

10. MOU Modifications. This MOU may only be modified by a written amendment executed by the Parties. Notwithstanding the foregoing, Exhibit A, Funding Commitments may be amended by simple majority of the Regional Climate Committee. Any such amendments shall automatically replace the Funding Commitments attached to this Agreement. RCEA shall distribute the Amended Contribution Schedule to all Parties.

11. Effective Date. This MOU shall become effective on the date that it is executed by a sufficient number of Municipal Jurisdictions whose respective populations together represent at least 85% of the overall population of Humboldt County as determined by the April 1, 2020 Population Census for Humboldt County.

12. Counterpart Execution: This MOU, and any amendments hereto, may be executed in one (1) or more counterparts, each of which shall be deemed to be an original and all of which, when taken together, shall be deemed to be one (1) and the same agreement. This MOU, and any amendments hereto, may be signed by manual or electronic signatures in accordance with any and all applicable local, state and federal laws, regulations and standards, and such signatures shall constitute original signatures for all purposes. A signed copy of this MOUJ, and any amendments hereto, transmitted by email or by other means of electronic transmission shall have the same legal effect as delivery of an original executed copy of this MOU and any amendments hereto.

13. Authority To Execute: Each person executing this MOU represents and warrants that he or she is duly authorized and has legal authority to execute and deliver this MOU. Each party represents and warrants to the other that the execution and delivery of this MOU and the performance of such party’s obligations hereunder have been duly authorized.

WITNESSETH, each Agency signing below has duly approved and adopted this Memorandum of Understanding in accordance with its respective requirements and duly authorized its execution. 61 ---------- September 18, 2026 DRAFT ---------

City of Arcata:

By:

Title:

Date:

City of Blue Lake:

By:

Title:

Date:

City of Eureka:

By:

Title:

Date:

City of Ferndale:

By:

Title:

Date:

City of Fortuna:

By:

Title:

Date:

City of Rio Dell:

By:

Title:

Date:

City of Trinidad:

By:

Title:

Date:

County of Humboldt:

By:

Title:

Date:

Humboldt County Association of Governments:

By:

Title:

Date:
62 ---------- September 18, 2026 DRAFT ---------

Humboldt County Transit Authority:

By:

Title:

Date:

Humboldt Waste Management Authority:

By:

Title:

Date:

Redwood Coast Energy Authority:

By:

Title:

Date:
63 Exhibit A
Funding Commitments
This schedule of Funding Commitments identifies the individual funding commitments made by the Parties for the term of the MOU. Funding commitments for the full term of the MOU commence the year the Party joins the MOU. Fiscal Year commitments are due to RCEA no later than December 1 of each Fiscal Year.

Agency Population Percent FY 26/27 FY 27/28 FY 28/29 FY 29/30 Arcata 19,001 14.2% 21,821.84 $ $ 21,821.84 $21,821.84 21,821.84 $ Blue Lake 1,136 0.8% 1,304.65 $ $ 1,304.65 $1,304.65 1,304.65 $ Eureka 26,122 19.5% 30,000.00 $ $ 30,000.00 $30,000.00 30,000.00 $ Ferndale 1,361 1.0% 1,563.05 $ $ 1,563.05 $1,563.05 1,563.05 $ Fortuna 12,198 9.1% 14,008.88 $ $ 14,008.88 $14,008.88 14,008.88 $ Rio Dell 3,232 2.4% 3,711.81 $ $ 3,711.81 $3,711.81 3,711.81 $ Trinidad 296 0.2% 339.94 $ $ 339.94 $339.94 339.94 $
County
(Unincorporated) 70,471

52.7% 80,932.93 $ $ 80,932.93 $80,932.93 80,932.93 $
133,817 100% $153,683.10 $153,683.10 $153,683.10 153,683.10 $ 64

Staff Report
Agenda Item # 12.2
Information
Agenda Date September 24, 2026
To Board of Directors
Prepared by Eileen Verbeck, Deputy Executive Director
Subject Approval of Fifth Lease Amendment Between GHD, Tenant, and RCEA, Landlord for 718 Third Street, Eureka CA
Background
Since 2020, RCEA has been working toward acquisition of an office building that would provide enough office space for existing staff, provide an on-site location for public meetings, and a space open to the public for educational and outreach material. In 2020, RCEA identified the need for a minimum of 10,000 sq ft for office space and public meetings.

In June 2026, RCEA purchased Assessor’s Parcel Number 001-135-007, 718 Third Street, Eureka CA.

The property is a total of 23,713 sq ft of building (16,588 sq ft office building and a 7,125 sq ft attached warehouse) on an approximately .61 acres parcel situated on 3rd Street between H & I Streets. The property is located within mixed-use Downtown (DT) zoning district and principally permitted uses include office, retail, and service, civic and instructional facilities.

The office portion of the premises is tenanted with a long-term lease agreement. RCEA began negotiations with the existing tenant to amend the existing lease to allow RCEA to take over occupancy for a portion of the finished office space. The tenant has agreed to amend the lease to reduce their occupied space by 4,341 sq ft, which would allow RCEA to occupy that space. In exchange for this reduction of the tenant-occupied space, RCEA will provide an incentive allowance of $300,000 that is applicable toward costs associated with downsizing.

Summary
The purchase of Assessor’s Parcel Number 001-135-007 resulted in RCEA taking over the existing Commercial Lease between the seller and tenant, GHD, Inc. RCEA has negotiated an amendment to this lease with the following terms:

1. Tenant shall vacate 4,341 sq ft on the first floor of the building.

2. RCEA to remeasure the tenant’s demised property after the relinquishment date to confirm the square footage used in determining monthly base rent.

3. RCEA at its sole cost and expense to do the following work: 1) constructing a wall on the western side of the relinquished space to separate the relinquished space from the demised premises, 2) constructing two doors to access the restroom located on the first floor, 3) constructing one new 65

door to allow tenant access to the existing server room on the first floor, 4) establishing and maintaining a method to identify and track utility usage attributable to the relinquished space.

4. Allow RCEA first right of refusal to retain furniture left in the relinquished space.

5. Establish a tenant incentive allowance of $300,000 applicable toward costs incurred by the tenant in connection with reconfiguration of the office space to accommodate relinquishing a portion of the building.

Financial Impact
RCEA staff estimate that rental income collected over the next three years will offset the full tenant improvement allowance.

Staff Recommendation
Approve Fifth Amendment to Commercial Lease Agreement between Redwood Coast Energy Authority, Landlord, and GHD Inc., Tenant, for 718 3rd Street and Authorize the Executive Director to Execute All Applicable Documents.

Attachments

1. Fifth Amendment to Lease Agreement Between Redwood Coast Energy Authority, Landlord, and GHD INC., Tenant
66 4900-3986-7304.3/375029.00008
Liberty Station
[First Amendment]
[GHD Services Inc.
and GHD Inc.]

FIFTH AMENDMENT TO LEASE AGREEMENT
This FIFTH AMENDMENT TO LEASE AGREEMENT ("Fifth Amendment") is made and entered into as of July ___, 2026 (the “Effective Date”), by and between Redwood Coast Energy Authority ("Landlord"), and GHD INC., a California corporation ("Tenant").

R E C I T A L S :

A. White House Finance Affiliate, a California corporation (predecessor in interest to Landlord) and Winzler & Kelly, a California corporation (predecessor in interest to Tenant) entered into that certain Office Lease dated July 9, 2009 (the "Original Lease"), as amended by that certain First Amendment to Lease Agreement, dated December 18, 2009 (the “First Amendment”); that certain Second Amendment to Lease Agreement, dated January 4, 2011 (the “Second Amendment”); that certain Third Amendment to Lease Agreement, dated July 3, 2020 (the “Third Amendment”); and that certain Fourth Amendment to Lease Agreement, dated October, 2025 (the “Fourth Amendment”). The First Amendment, Second Amendment, Third Amendment and Fourth Amendment, together with the Original Lease are referred to herein collectively as, the “Lease”).

B. Pursuant to the Lease, Tenant leases approximately 16,588 square feet of separately demised space on the first and second floors (the “Original Demised Premises”) of the building located at 718 3rd Street (between H & I Streets), Eureka, California 95501 (the "Building").

C. Landlord recently acquired the Building, and Landlord and Tenant desire to amend the Lease to reduce the square footage included in the Original Demised Premises by 4,341 square feet, in accordance with the terms and conditions set forth in this Fifth Amendment.

A G R E E M E N T :

NOW, THEREFORE, in consideration of the foregoing recitals and the mutual covenants contained herein, and for other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, the parties hereto hereby agree that as of the Effective Date, the Lease is amended as follows:

1. Terms. All capitalized terms when used herein shall have the same respective meanings as are given such terms in the Lease unless expressly provided otherwise in this Fifth Amendment.

2. Fundamental Terms and Attachments. In Section 1, FUNDAMENTAL TERMS AND ATTACHMENTS, Subsection (a), Fundamental Terms, the definitions of the Fundamental Terms described below shall be deleted in the Lease and replaced with the following definitions, (or merely added to the Fundamental Terms if there is no referenced definition in the Lease to delete):
“(i) Landlord: The Redwood Coast Energy Authority (RCEA), 67 -2-
a California public joint powers authority
633 3rd Street
Eureka, CA 95501
(ii) Tenant: GHD, INC, a California corporation
718 3rd Street
Eureka CA, 95501
With a copy to:

GHD
455 Phillip Street Unit #100A
Waterloo Ontario N2L 3X2 Canada
Attn: Romin Jarrah
[email protected]
(iv) Demised Premises:

The Demised Premises as of the Effective Date of this
Amendment is depicted in Exhibit A and is the Original
Demised Premises. Beginning on the Relinquishment Date
(as defined below), Demised Premises shall mean 12,247
square feet of separately demised space on the first and second floors of the Building (defined below), as shown on Exhibit C, attached hereto.
(v) Building: The 2-story building located on 3rd Street (between H & I Streets), Eureka, California.
(xxix) Intentionally deleted
(xxx) Original Demised Premises: As defined in Recital B of the Fifth Amendment and depicted in Exhibit A, attached hereto.
(xxxi) Landlord’s Work: As defined in Section 7 of the Fifth Amendment. (xxxii) Relinquishment Date: As defined in Section 4 of the Fifth Amendment. (xxxiii) Relinquished Space: As defined in Section 4 of the Fifth Amendment. (xxxiv) Tenant’s Incentive Allowance: As defined in Section 8 of the Fifth Amendment.”
To the extent the Fundamental Terms are not amended above, the Fundamental Terms shall remain the same as they are in the Lease.
68 -3-

3. Fundamental Terms and Attachments. Section 1, FUNDAMENTAL TERMS AND ATTACHMENTS, Subsection (b), Exhibits, is hereby deleted and replaced in its entirety with the following Exhibits, attached hereto and, by this reference, incorporated herein:
“EXHIBIT “A”- Site Plan of Original Demised Premises.

EXHIBIT “B”- Depiction of Relinquished Space.

EXHIBIT “C” - Demised Premises”

4. Demised Premises.

On or before the date that is thirty (30) days after the date the Landlord’s Work is completed (the “Relinquishment Date”), Tenant shall vacate the 4,341 square feet on the first floor of the Building, as shown on Exhibit B, (the “Relinquished Space”). As of the Relinquishment Date, the defined term “Demised Premises” as used herein and in the Lease shall refer to the 12,247 square feet designated as the Demised Premises on Exhibit C.

5. Remeasurement, Monthly Base Rent.

Monthly Base Rent, Tenant’s Share, and any other amounts in the Lease based on the square footage of the Original Demised Premises shall, as of the Relinquishment Date, be re-calculated based on the square footage of the Demised Premises, and any excess amounts paid by Tenant prior to the Relinquishment Date that apply to periods after the Relinquishment Date shall be credited toward the next payment of such amounts due from Tenant.

Within one hundred eighty (180) days after the Relinquishment Date, Landlord shall provide to the Tenant a certificate of measurement from the Landlord’s surveyor verifying the rentable area of the Demised Premises in accordance with the BOMA 1996 Industry Standards. The Monthly Base Rent, Tenant’s Share, and any other amounts in the Lease shall be determined in accordance with the certified square footage as of the date of remeasurement.

6. Conditions Precedent and Cost Sharing. Section 31, CONDITIONS PRECEDENT FOR TENANT’S BENEFIT, Section 32, CONDITIONS PRECEDENT FOR LANLORD’S BENEFIT, and, Section 33, COST SHARING, are hereby deleted.

7. Landlord’s Work. Landlord shall, at its sole cost and expense, be responsible for all work described in this Section 7 (collectively, the “Landlord’s Work”), which shall include, without limitation, (i) constructing a wall on the western side of the Relinquished Space to separate the Relinquished Space from the Demised Premises, (ii) completion of the Shared Restroom (as defined below), (iii) completion of the Tenant Server Room (as defined in Section 7(c), below), as shown on Exhibit B, and (iv) completion of the New Door and Landlord’s Cable Work (both as defined in Section 7(c), below . Landlord shall complete Landlord’s Work on or before September 1, 2027, subject to extension by Landlord after obtaining Tenant’s written consent, which shall not be unreasonably withheld so long as such extension is required due to factors outside the 69 -4-
reasonable control of Landlord to allow for completion of Landlord’s Work. Landlord shall provide written notice to Tenant of the estimated date of completion of Landlord’s Work no less than sixty (60) days prior to the estimated date of completion of Landlord’s Work.

A. Separate Utility Meters. Landlord shall, at its sole cost and expense, establish and maintain a method, that may include separate metering if feasible, to reasonably identify and track utility usage attributable to the Relinquished Space which utility usage shall be paid by Landlord beginning on the Relinquishment Date. Tenant is responsible for paying for utilities as specified in accordance with Sections 5(e) and 10 of the Lease until separate metering is installed.

B. Shared Restroom. Landlord shall, at its sole cost and expense, construct two (2) new doors to access the restroom located on the first floor (the “Shared Restroom”). One door shall be solely for Tenant’s access to the Shared Restroom and will be constructed on the western side of the Shared Restroom. The other door shall be solely for Landlord’s access to the Shared Restroom and will be constructed on the eastern side of the Shared Restroom. Each of the two doors will contain a keypad to restrict access into the Demised Premises and the Relinquished Space so that neither party has access to the other party’s space.

C. Tenant Server Room. Landlord shall, at its sole cost and expense, construct one (1) new door (the “New Door”) to allow Tenant access from the Demised Premises as of the Relinquishment Date to the existing server room located on the first floor (the “Tenant Server Room”) and seal the door that is located in the Relinquished Space. The New Door shall be solely for Tenant’s access to the Tenant Server Room and will be constructed on the western side of the existing Tenant Server Room. In addition, at Landlord’s sole cost and expense, Landlord shall (i) cut back and label existing CAT 6 ethernet cables for all data circuits serving the Relinquished Space from the existing patch panel in the Tenant Server Room and (ii) relocate the cut back CAT 6 ethernet cables to the new space that will serve as Landlord’s server room for Landlord’s future use (collectively, “Landlord’s Cable Work”).

D. Standard of Work. The Landlord’s Work shall be completed in a good and workmanlike manner, using new materials, and in compliance with all laws, ordinances, and regulations. It shall be Landlord’s obligation, at its sole cost and expense, to repair, replace, maintain, and clean the Shared Restroom as part of Landlord’s obligations for Common Areas described in Section 9 of the Lease; provided, that, the costs to repair, replace, maintain, and clean the Shared Restroom shall not be included in Operating Expenses charged to Tenant.

E. Relinquished Furniture. On or before the date that is fourteen (14) days prior to the Relinquishment Date, Landlord shall identify any of Tenant’s furniture located in the Relinquished Space that Landlord elects to retain (“Relinquished Furniture”). Tenant shall not remove the Relinquished Furniture, and on the Relinquished Date, the Relinquished Furniture shall become the property of Landlord. After Landlord’s identification of the Relinquished Furniture in accordance with this Section 7(e) and before the Relinquishment Date, Tenant shall remove, at Tenant’s sole cost, all furniture in the Relinquished Space that is not identified as Relinquished Furniture. Tenant makes no representations or warranties regarding the condition of the Relinquished Furniture and Landlord accepts the Relinquished Furniture in its AS-IS condition on the Relinquishment Date.
70 -5-

8. Tenant Incentive Allowance. As an incentive for Tenant to relinquish the Relinquished Space, Landlord shall provide to the Tenant an incentive allowance of Three Hundred Thousand Dollars ($300,000.00) (the “Tenant Allowance”) applicable toward all costs incurred by Tenant in connection with the reconfiguration of the Demised Premises after Tenant relinquishes the Relinquished Space, including, without limitation, any new furniture, fixtures, and equipment purchased for the Demised Premises (collectively, the “Reconfiguration Costs”).

Landlord shall pay to the Tenant the Tenant Allowance within ten (10) business days after Tenant delivers an invoice to Landlord therefor.

A. Labor Code Compliance. All repair, remodel, construction, and other work as defined in California Labor Code Section 1770 that Tenant undertakes either on the Building or utilizing the Tenant Allowance is subject to conformance with California Labor Code regarding the payment of prevailing wage, and compliance with all other applicable Labor Code laws.

9. Extensions. The Parties acknowledge Tenant’s remaining right to extend the Term of the Lease in accordance with Section 4 of the Lease remains in full force and effect.

10. Electronic Signatures. The parties agree that this Fifth Amendment may be signed and/or transmitted by electronic mail of a .PDF document or electronic signature (e.g., DocuSign or similar electronic signature technology) and thereafter maintained in electronic form, and that such electronic record shall be valid and effective to bind the party so signing as a paper copy bearing such party's hand-written signature. The parties further consent and agree that the electronic signatures appearing on this Fifth Amendment shall be treated, for purpose of validity, enforceability and admissibility, the same as hand-written signatures.

11. Notices. All notices or other communications required or permitted to be given under this Fifth Amendment shall be in writing and shall be deemed to have been given when delivered if personally delivered, or three (3) business days after mailing if mailed by certified mail, postage prepaid, return receipt requested, or via email, return receipt requested, and shall be addressed as follows:

Notices shall be given to RCEA at the following address:

Eileen Verbeck, Deputy Executive Director
Redwood Coast Energy Authority
633 3rd Street
Eureka, CA 95501
[email protected]
Notices shall be given to TENANT at the following address:

GHD
455 Phillip Street Unit #100A
Waterloo Ontario N2L 3X2 Canada
Attn: Romin Jarrah
[email protected]

12. No Further Modification; Conflict. Except as specifically set forth in this Fifth Amendment, all of the terms and provisions of the Lease shall remain unmodified and in full force 71 -6-
and effect. In the event of a conflict between the terms of the Lease and this Fifth Amendment, the terms of this Fifth Amendment shall prevail.

IN WITNESS WHEREOF, this Fifth Amendment has been executed as of the day and year first above written.

TENANT LANDLORD
GHD Inc., a California corporation Redwood Coast Energy Authority By: ________________________ By: ________________________ Name: ______________________ Name: ______________________ Title: _______________________ Title: _______________________ 72 This page
intentionally left
blank.
73 EXHIBIT A – ORIGINAL DEMISED PREMISES
First floor of Original Demised Premises
Warehouse Excluded
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74 Second floor of Original Demised Premises.

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75 EXHIBIT B – RELINQUISHED SPACE
Relinquished Space
Tenant
Shared Restrooms
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76 EXHIBIT C – DEMISED PREMISES
First floor of Original Demised Premises
Excluded
:,-- 7
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77 Second floor of Original Demised Premises.

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78

Staff Report
Agenda Item # 12.3
Information
Agenda Date September 24, 2026
To Board of Directors
Prepared by Eileen Verbeck, Deputy Executive Director
Mike Avcollie, Capital Asset Manager
Subject Recommended Design-Build Procurement for 718 3rd Street Office Remodel Summary
Staff are seeking Board approval to utilize a design-build procurement process for the commercial remodeling of 718 and 720 3rd Street, Eureka. Solicitation documents will include a Request for Qualifications and a Request for Proposals. Staff are also requesting the formation of an Ad Hoc Subcommittee with delegated authority to make interim decisions concerning the design-build procurement.

Background
In June 2026, RCEA purchased the commercial property at 718 and 720 3rd Street, Eureka. The property includes a vacant 7,125 sq ft attached warehouse. As outlined in a staff report presented earlier in the meeting, RCEA has negotiated a fifth lease amendment that outlines the tenant will vacate 4,341 sq ft of finished office space on the first floor of the building. This relinquished space is adjacent to the vacant warehouse. Additionally, the fifth lease amendment requires that RCEA complete improvements that would allow a separation of the space occupied by the tenant and the space that RCEA plans to occupy.

The type of work for which RCEA plans to issue a solicitation include the following:
• Complete design and seek necessary permitting.
• Complete landlord improvements as specified in the fifth lease amendment. • Connect the relinquished space currently occupied by GHD to the warehouse. • Build out the warehouse and relinquished space to have a public lobby, ADA compliant entrance, ADA bathrooms, office space, public meeting room, and break room.

The Design-Build process is a project delivery process in which one entity, known as the Design-Build Entity (DBE), is responsible for both design and construction of a project under a single contract.

Rationale for Recommended Action
79

California Public Contract Code 22160 et seq. allows for utilizing a design-build procurement pathway for public projects exceeding a cost of $1M as an alternative to using the standard Public Project Contracting process (as detailed in RCEA’s Procurement Policy), design-bid-build. The total cost to design and construct the necessary upgrades to the warehouse space is expected to be, and is budgeted for, more than $1M. The design-build process includes the following steps:

1. Develop and issue a Request for Qualifications (RFQ);

2. Prepare a recommended shortlist of qualified design-build contractors based on the responses to the RFQ;

3. Issue a Request for Proposals (RFP) to invite the shortlisted contractors to submit competitive sealed bids for the design-build contract;

4. Award the design-build contract based on a “best value” evaluation of any responsive bid, which includes consideration of price, technical design and expertise, and lifecycle costs of the proposed design.

Advantages of the Design-Build approach include:
• Single point of responsibility- the owner (RCEA) interacts with one entity that is accountable for all aspects of design and construction. This can reduce finger pointing between separately contracted design and construction firms when conflicts occur and/or when changes are required. • Allows for “best value” evaluation of proposals by RCEA that can include other aspects than just price (for example, ability to meet the desired schedule; availability of skilled and trained workforce, etc.)
• Allows for “value engineering” that incorporates the owners' input on design while minimizing costs during the design process.
• Increases likelihood of success -- the design team is integrated into the construction team and is less likely to design using products, materials, and methods that could cause cost overruns, change orders, or time delays.
• Can allow for accelerated schedule -- the single Design-Build Entity can begin parts of construction (demolition, short term modifications) while the design team is still completing design and permitting.

The key advantage to the design-build approach for this project is that it would greatly increase the likelihood of receiving responsive and competitive bids for the office remodel and allows RCEA to consider the total cost of the project without committing a large amount of funding to the design process absent the knowledge of potential construction costs.

Authorizing the Executive Director to initiate the first step of the design-build process and authorizing an Ad Hoc Committee to approve a resulting shortlist and issuance of the RFP would help to keep the project on track for completion within the desired timeline.

Equity Impacts
This is Operations; not directly applicable.
80

Alignment with RCEA’s Strategic Plan
The building design will support electrification and utilize energy efficiency best practices.

Financial Impact
RCEA is currently applying for a low-interest loan to recover the cost of purchasing the building. The funding to complete the building design and construction improvements is contingent on receiving the loan funds.

Staff Recommendation
Authorize RCEA’s Executive Director to utilize the design-build process to procure design and construction of the commercial remodel and improvements to 718 3rd St. Eureka; and initiate the first step by developing and issuing a Request for Qualifications.

Create an Ad Hoc Building Remodel Solicitation Committee comprised of five or fewer RCEA Board members.

Delegate authority to the Building Remodel Solicitation Ad Hoc Committee to: 1) approve the short list of qualified design build contractors, and 2) authorize the Executive Director to issue a Request for Proposals for construction of the commercial remodel/improvements at 718 and 720 3rd St. Eureka.

Attachments
None.
81 This page
intentionally
left blank.
82 APN 001-135-007
718 3rd Street Eureka
Design Build Procurement 718 3rd St Eureka
Existing Conditions
• 23,713 sf (16,588 sq ft office building and 7,125 sf
warehouse)
• Constructed in 1950, remodel in 2010
Design Build Procurement 718 3rd St Eureka
Renovations:
• Complete “Landlord’s Work” per Lease Amendment
• Convert warehouse to office space with ADA
entrance, ADA bathrooms, space for public meetings.
• Integrate new office Mechanical, Electrical, Plumbing with “relinquished space”
Design Build Procurement 718 3rd St Eureka
Design Build Procurement 718 3rd St Eureka
What is Design Build?:
• Design-Build process is a project delivery process in which one entity, known as the Design-Build Entity
(DBE), is responsible for both design and construction
of a project under a single contract
Design Build Procurement 718 3rd St Eureka
Why use Design Build?:
• Single procurement process and single contract to manage • Allows for “best value” evaluation of proposals by RCEA • Allows for “value engineering” that incorporates the owners' input on design while minimizing costs during the design process • Increases likelihood of success/mitigates risk; design team is integrated into the construction team and can design using products, materials, and methods to avoid cost overruns, change orders, or time delays. • Can allow for accelerated schedule
Design Build Procurement 718 3rd St Eureka
What is the process?:
• Develop and issue a Request for Qualifications (RFQ); • Prepare a recommended shortlist of qualified design-build entities based on the responses to the RFQ;
• Issue a Request for Proposals (RFP) to invite the shortlisted entities to submit competitive sealed bids for the design-build contract; • Award the design-build contract based on a “best value” evaluation of any responsive bid, which includes consideration of price, technical design and expertise, and lifecycle costs of the proposed design.

Next Steps:
• Develop and issue a Request for Qualifications (RFQ); • Prepare a recommended shortlist of qualified design-build entities based on the responses to the RFQ;
• Issue a Request for Proposals (RFP) to invite the shortlisted entities to submit competitive sealed bids for the design-build contract; • Award the design-build contract based on a “best value” evaluation of any responsive bid, which includes consideration of price, technical design and expertise, and lifecycle costs of the proposed design.

Staff Report
Agenda Item # 12.4
Information
Agenda Date September 24, 2026
To Board of Directors
Prepared by Stephen Kullmann, Director of Customer Programs Richard Engel, Director of Power Resources
Subject Overview of Distributed Energy Resources and Virtual Power Plants Summary
In response to interest expressed by Board members, staff will provide a presentation on distributed energy resources and virtual power plants, and potential opportunities for RCEA in this topic area.

Equity Impacts
None - this item is information only.

Alignment with RCEA’s Strategic Plan
This topic relates to numerous strategies in RCEA's strategic plan. Chief among them:

2.1.5 Integrate Distributed Energy Resources. Develop and implement customer programs that support, promote and integrate distributed energy resources, including but not limited to grid-connected generation, energy storage, energy efficiency, electric vehicle and demand response technologies.

2.1.6 Integrate a Distributed Energy Resource Management System. Support the development and installation of systems needed for effective and responsive management of distributed energy resources.

Evaluate the potential integration of distributed energy resources into a unified system that would allow RCEA to aggregate and automate demand response activities

2.3.1 Implement Demand Response and Distributed Energy Resource Programs. Support and prioritize demand response programs that offer customers a role in balancing energy usage with the availability of electricity on the grid. Demand response programs and offerings will, where possible, integrate with distribution-connected efficiency systems and controls, renewable energy generation, and energy storage measures. Where feasible, energy technologies will be controllable and integrated as a distributed resource; any such efforts will require customer education and approval and will be implemented with a commitment to respecting and protecting customers’ rights to privacy. 83

2.3.2 Support Reduced Energy Use During Peak Hours and Peak Event Days. Notify, support, and enable action from customers who choose to participate by shifting energy usage to off-peak hours, reduce daily energy usage during peak hours, and/or reduce energy usage during peak event days.

2.3.3 Enable Automated Demand Response. Install communicable controls with electrification, efficiency, and storage technologies that automatically reduce energy use during demand response events. Implement building demand response systems that allow for the curtailment of loads without major impacts to occupants and operations.

Financial Impact
As no board action is requested on this item, there is no associated financial impact.

Staff Recommendation
None – information only.

Attachments
None. Informational slides on this topic will be presented to the Board at the meeting. 84