Redwood Coast Energy Authority
633 3rd Street, Eureka, CA 95501
Phone: (707) 269-1700 Toll-Free (800) 931-7232 Fax: (707) 269-1777 E-mail: [email protected] Web: www.redwoodenergy.org
BOARD OF DIRECTORS MEETING AGENDA
September 22, 2022 -Thursday, 3:30 p.m.
COVID-19 NOTICE
RCEA AND HUMBOLDT BAY MUNICIPAL WATER DISTRICT OFFICES
WILL NOT BE OPEN TO THE PUBLIC FOR THIS MEETING
Pursuant to the Governor’s Executive Order N-29-20 of March 17, 2020, and revised Brown Act provisions signed into law on September 16, 2021, the RCEA Board of Directors meeting will not be convened in a physical location. Board members will participate in the meeting via an online Zoom video conference.
To listen to the meeting by phone, call (669) 900-6833 or (669) 444-9171. Enter webinar ID:
819 7236 8051. To watch the meeting online, join the Zoom webinar at https://us02web.zoom.us/j/81972368051.
You may submit written public comment by email to [email protected].
Please identify the agenda item number in the subject line. Comments will be included in the meeting record but not read aloud during the meeting.
To make a comment during the public comment periods, raise your hand in the online Zoom webinar, or press star (*) 9 on your phone to raise your hand. When it is your turn to speak, a staff member will ask you to unmute your phone or computer. You will have 3 minutes to speak.
While downloading the Zoom application may provide a better meeting experience, Zoom does not need to be installed on your computer to participate. After clicking the webinar link above, click “start from your browser.”
In compliance with the Americans with Disabilities Act, any member of the public needing special accommodation to participate in this meeting should call (707) 269-1700 or email [email protected] at least 3 business days before the meeting. Advance notice enables RCEA staff to make their best effort to reasonably accommodate access to this meeting while maintaining public safety.
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 of Directors, including those received less than 72 hours prior to the RCEA Board meeting, will be made available to the public at www.redwoodenergy.org.
OPEN SESSION Call to Order
1 RCEA September 22, 2022, Board of Directors Meeting Agenda
1. REPORTS FROM MEMBER ENTITIES
2. ORAL 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.
3. CONSENT CALENDAR
All matters on the Consent Calendar are considered to be 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.
3.1 Approve Minutes of August 25, 2022, Board Meeting.
3.2 Approve Disbursements Report.
3.3 Accept Financial Reports.
3.4 Extend Resolution No. 2022-6 Ratifying Governor Newsom’s March 4, 2020, State of Emergency Proclamation and Authorizing Remote Teleconference Meetings of RCEA’s Legislative Bodies, for the period September 22, 2022, through October 21, 2022, pursuant to Brown Act revisions of AB 361.
4. REMOVED FROM CONSENT CALENDAR ITEMS
Items removed from the Consent Calendar will be heard under this section.
5. OLD BUSINESS
5.1. Foster Clean Power A Solar Plus Storage Power Purchase Agreement - CPUC Mid-Term Reliability Procurement
Approve Power Purchase Agreement with Foster Clean Power A LLC and authorize the Executive Director to execute all applicable documents.
6. NEW BUSINESS
6.1. Rural Electric Vehicle Charging CEC Grant
Approve accepting CEC Rural Electric Vehicle Charging Grant in the amount of $700,000 and authorize $175,000 in RCEA match funds for a total project cost of $875,000 and authorize the Executive Director to execute the Grant Agreement and any associated documents necessary to secure the grant following review and approval by RCEA General Counsel.
COMMUNITY CHOICE ENERGY (CCE) BUSINESS (Confirm CCE Quorum) 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. OLD CCE BUSINESS
2 RCEA September 22, 2022, Board of Directors Meeting Agenda
7.1. Renewable America North Bank Road Projects Update – CPUC Mid-Term Reliability Procurement
Authorize staff to continue negotiations with Renewable America of a long-term power purchase agreement for the 5 MW North River Clean Power solar plus storage project.
8. NEW CCE BUSINESS
8.1. 2022 Integrated Resource Plan Portfolio Review
Provide feedback to staff on the proposed Integrated Resource Plan portfolio.
END OF COMMUNITY CHOICE ENERGY (CCE) BUSINESS
9. STAFF REPORTS
9.1. Executive Director’s Report
10. FUTURE AGENDA ITEMS
Any request that requires Board action will be set by the Board for a future agenda or referred to staff.
11. CLOSED SESSION
11.1 Conference with real property negotiators pursuant to Government Code § 54956.8 in re: APNs 001-141-005 and 001-141-006; RCEA negotiator: Executive Director; Owner’s negotiating party: Wells Commercial; Under negotiation: price and terms.
12. RECONVENE TO OPEN SESSION
13. CLOSED SESSION REPORT
14. ADJOURNMENT
NEXT REGULAR MEETING
Thursday, October 27, 2022, 3:30 p.m.
Meeting location to be determined. Online and phone participation options will be available. 3 Redwood Coast Energy Authority
633 3rd Street, Eureka, CA 95501
Phone: (707) 269-1700 Toll-Free (800) 931-7232 Fax: (707) 269-1777 E-mail: [email protected] Web: www.redwoodenergy.org
BOARD OF DIRECTORS DRAFT MEETING MINUTES
August 25, 2022 - Thursday, 3:30 p.m.
Notice of this meeting was posted on August 20, 2022. Vice Chair Chris Curran called a regular meeting of the Board of Directors of the Redwood Coast Energy Authority to order on the above date at 3:34 p.m., stating that the teleconference meeting was being conducted pursuant to the AB 361 Brown Act open public meeting law revisions signed into law on September 16, 2021, and Governor Newsom’s State of Emergency Proclamation of March 4, 2020. Vice Chair Curran stated that the posted agenda contained public teleconference meeting participation instructions.
PRESENT: Chair Stephen Avis (left 5 p.m.), Scott Bauer, Rex Bohn (left 5:30 p.m.), Vice Chair Chris Curran, Mike Losey Jack Tuttle (arrived 4:09 p.m.), Frank Wilson, Sheri Woo.
ABSENT: Sarah Schaefer. STAFF AND OTHERS PRESENT: Business Planning and Finance Director Lori Biondini; General Counsel Nancy Diamond; Power Resources Director Richard Engel; Senior Power Resources Manager Jocelyn Gwynn; Executive Director Matthew Marshall; Administration Specialist Meredith Matthews; Community Strategies Manager Nancy Stephenson; Clerk of the Board Lori Taketa; Deputy Executive Director Eileen Verbeck.
ORAL COMMUNICATIONS
There were no public comments on items not on the agenda. Vice Chair Curran closed the oral communications portion of the meeting.
CONSENT CALENDAR
3.1 Approve Minutes of July 28, 2022, Board Meeting.
3.2 Approve Disbursements Report.
3.3 Accept Financial Reports.
3.4 Extend Resolution No. 2022-6 Ratifying Governor Newsom’s March 4, 2020, State of Emergency Proclamation and Authorizing Remote Teleconference Meetings of RCEA’s Legislative Bodies, for the Period August 27, 2022, Through September 25, 2022, Pursuant to Brown Act Revisions of AB 361.
3.5 Authorize the Executive Director to Execute an Amendment for a Six-Month Extension of the Commercial Office Lease for RCEA’s Existing Headquarters at 633 3rd Street, Eureka, CA.
3.6 Approve Amendment to Professional Services Agreement with Aiqueous for Demand-Side Management Database Development and Operation Services, Increasing the Not-to-Exceed Amount to $334,000 Through December 2023, and Authorize the Executive Director to Prepare and Execute All Applicable Documents, Including Contract Extension Provisions.
3.7 Approve Amendment to Master Services Agreement with Schatz Energy Research Center for Programmatic Research and Development Technical Support Services, 4 RCEA August 25, 2022, Board of Directors Meeting DRAFT Minutes
Increasing the Not-to-Exceed Amount From $100,000 to $250,000 Through June 2025, and Authorize the Executive Director to Prepare and Execute All Applicable Documents.
3.8 Authorize staff to Develop and Execute a Contract with the Bear River Band of the Rohnerville Rancheria for the Reimbursement of Installing Mobile Home Solar at Two Agreed Upon Locations Not to Exceed a Total Project Cost of $29,700.00, Pending Final Contract Review and Approval by RCEA General Counsel Prior to Execution.
3.9 Authorize Staff to Solicit Bids for Electrical Portions of Construction Work at the Eureka 3rd and H Streets Electric Vehicle Charging Site for a Budget Not to Exceed $56,000 and Authorize the Executive Director to Execute All Applicable Documents With the Lowest Responsive Bidder.
3.10 Accept Quarterly Budget Report (Q4).
Director Woo requested items 3.5 and 3.9 be removed and Director Wilson requested items
3.6, 3.7 and 3.8 be removed from the consent calendar.
M/S: Avis, Woo: Approve consent calendar items 3.1, 3.2, 3.3, 3.4, and 3.10.
The motion passed with a unanimous roll call vote. Ayes: Avis, Bauer, Bohn, Curran, Losey, Wilson, Woo. Noes: None. Absent: Schaefer, Tuttle. Abstain: None.
The directors requested excluding non-routine items from the consent calendar and confirmation that legal counsel has examined and approved all agreements. Staff and the Board reviewed the agency’s agreement legal review process. Directors noted items 3.6 and
3.7 involved increases to budgeted amounts and requested greater transparency and explanation of these areas during the budget process.
M/S: Woo, Avis: Approve consent calendar items 3.5, 3.6, 3.7, 3.8, and 3.9.
The motion passed with a unanimous roll call vote. Ayes: Avis, Bauer, Bohn, Curran, Losey, Tuttle, Wilson, Woo. Noes: None. Absent: Schaefer. Abstain: None.
Vice Chair Curran confirmed there was a quorum to conduct Community Choice Energy business.
OLD CCE BUSINESS
5.1 2021 Power Source Disclosure Attestation
Power Resources Director Engel spoke about the customer report on power sources used during the previous year. Due to energy market volatility in 2021 and the agency’s resulting difficult financial situation, power from less expensive renewable sources was purchased.
Out-of-state solar, which has less rigorous chain-of-custody accounting and must be assumed to have some emissions, was included in RCEA’s REpower+ 100% renewable product. As a result, the mailed report shows the 2021 REpower+ product having some greenhouse gas emissions. In the future, only in-state renewables will be used for the REpower+ power portfolio.
5 RCEA August 25, 2022, Board of Directors Meeting DRAFT Minutes
There were no responses from the public to Vice Chair Curran’s invitation for comment and the public comment period was closed.
M/S: Avis, Bauer: Adopt Resolution 2022-7 Approving and Attesting to the Veracity of RCEA’s 2021 Power Source Disclosure Report and Power Content Label.
The motion passed with a unanimous roll call vote. Ayes: Avis, Bauer, Bohn, Curran, Losey, Tuttle, Wilson. Noes: None. Absent: Schaefer. Abstain: None. Non-Voting: Woo.
NEW CCE BUSINESS
6.1 Zero-Emission Resource Mid-Term Reliability Request for Offers Power Resources Senior Manager Gwynn reported on the CPUC decision requiring load serving entities (LSEs) to procure new capacity to replace the Diablo Canyon nuclear plant’s ability to produce a steady flow of energy during critical evening hours.
The directors discussed the desirability of local projects and expressed frustration with fulfilling state requirements in ways that do not benefit local energy production, reliability or clean energy needs. Staff described the Fairhaven energy storage project’s potential long-term benefit of storing offshore wind-generated electricity for use during low renewable energy supply times, and the importance of meeting state requirements in ways that move the agency toward fulfilling local goals.
There were no responses from the public to Vice Chair Curran’s invitation for comment and the public comment period was closed.
M/S: Losey, Bohn: Authorize staff to issue the Request for Offers for Zero-Emission Resources, in accordance with the terms provided.
Expand the scope of the Board ad hoc Mid-Term Reliability Solicitation Subcommittee to review and approve the following actions provided they are consistent with the RFO: (i) the offer shortlist, (ii) replacement of offers on the shortlist if negotiations with a shortlisted respondent are discontinued, and (iii) continued negotiations with a shortlisted respondent whose offer changes during the negotiation process.
Authorize staff to engage with the shortlisted respondents, including execution of exclusivity agreements, collection of shortlist deposits, and negotiation of contract terms, prior to full Board review and approval of resulting contracts.
The motion passed with a unanimous roll call vote. Ayes: Avis, Bauer, Bohn, Curran, Losey, Tuttle, Wilson. Noes: None. Absent: Schaefer. Abstain: None. Non-Voting: Woo.
OLD BUSINESS
7.1.Quarterly (Q2) CAPE/RePower Strategic Plan Status Update (Information only) Executive Director Marshall described agency progress toward strategic plan goals achieved in the last six months, including:
• A $700,000 California Energy Commission grant to install additional electric vehicle charging stations in rural County areas
• Submission of a Rural Regional Energy Network application to the CPUC 6 RCEA August 25, 2022, Board of Directors Meeting DRAFT Minutes
• Local firefighter training to fight solar battery storage fires • Airport microgrid commercial operations and successful islanded operation • Discussions with PG&E on Willow Creek and Hoopa microgrid development • Fairhaven battery storage procurement
• $1.46 million payment received in bill credits for RCEA customer unpaid bills • Working with CORE Hub on regional energy resilience collaboration • Working with Sonoma Clean Power on regional transmission planning.
Executive Director Marshall described the upcoming Bureau of Ocean Energy Management lease auction and Humboldt Wind Energy Area development in the context of the state’s ambitious renewable energy production goals and timeline. Any Humboldt offshore wind project over 150 MW will require upgraded transmission lines. Full development of both Humboldt lease areas will be necessary to achieve California’s 5,000 MW by 2030 goal.
Achievement of the 25,000 MW by 2045 goal requires offshore wind development off Del Norte County, Cape Mendocino and Humboldt County. Transmission infrastructure upgrades will cost between $5 and $10 billion and will require commercial viability of the Humboldt and another northern California offshore wind area to be feasible. Transmission upgrades will need to begin soon as this type of development takes a very long time.
There were no responses from the public to Vice Chair Curran’s invitation for comment and the public comment period was closed.
7.2.Offshore Wind Development Cooperative Agreement, Agreement in Principle Legal Counsel Diamond reviewed proposed Offshore Wind Development Cooperative Agreement changes resulting from changes in RCEA’s partner companies, and reasons for replacing the Cooperative Agreement with an Agreement in Principle that will address the Bureau of Ocean Energy Management’s increased scale of proposed development in the Humboldt Wind Area, potential energy offtaking arrangements, the RCEA-project company relationship during project development and operation, Interconnection Agreement ownership if the project company does not acquire a lease, and commitments to engage the community and stakeholders in project development, including hiring and training local skilled labor. This Agreement in Principle may need to be signed prior to the BOEM lease auction. Staff wants to retain the ability to influence who the grid interconnection queue position should be sold to should Redwood Offshore Wind not obtain a lease.
There were no responses from the public to Vice Chair Curran’s invitation for comment and the public comment period was closed.
M/S: Avis, Bauer:
1. Approve Third Amendment to Cooperation Agreement;
2. Approve Termination of Cooperation Agreement;
3. Approve Agreement in Principle;
4. Authorize the Executive Director to execute all such documents.
The motion passed with a unanimous roll call vote. Ayes: Bauer, Curran, Losey, Tuttle, Wilson, Woo. Noes: None. Absent: Avis, Bohn, Schaefer. Abstain: None. 7 RCEA August 25, 2022, Board of Directors Meeting DRAFT Minutes
STAFF REPORTS
9.1.Executive Director’s Report
Executive Director Marshall described the Federal Inflation Reduction Act’s energy incentives which support many of RCEA’s existing programs, including home energy efficiency and electrification and alternative fuel transportation programs.
FUTURE AGENDA ITEMS
Staff will schedule a Finance Subcommittee meeting to discuss supplemental budget items in more detail.
CLOSED SESSION
There was no new information to share nor actionable items regarding closed session item:
11.1 Conference with real property negotiators pursuant to Government Code § 54956.8 in re: APNs 001-141-005 and 001-141-006; RCEA negotiator: Executive Director; Owner’s negotiating party: Wells Commercial; Under negotiation: price and terms.
The directors declined adjourning to closed session. Vice Chair Curran adjourned the meeting at 5:57 p.m.
Lori Taketa
Clerk of the Board
8 Accrual Basis Redwood Coast Energy Authority
Disbursements Report
As of July 31, 2022
Type Date Num Name Memo Amount
Liability Check 07/07/2022 E-pay EDD Taxes -6,592.87
Liability Check 07/07/2022 E-pay Internal Revenue Service Taxes -30,040.76 Liability Check 07/07/2022 E-pay EDD Taxes -7.86
Liability Check 07/07/2022 ACH Newport Group Deferred compensation contributions -17,212.30 Check 07/08/2022 13858 - 66 NEM Customers NEM Closeout Acct #8440055967 -593.68 Bill Pmt -Check 07/08/2022 13867 Amazon.com monthly billing - June 2022 -2,508.87 Bill Pmt -Check 07/08/2022 13868 Arcata Chamber of Commerce Membership dues -440.00 Bill Pmt -Check 07/08/2022 13869 AT&T Long Distance Phone charges 6/25 - 7/24/2022 -136.73 Bill Pmt -Check 07/08/2022 13870 Braun Blaising & Wynne Legal Services - Regulatory -May 2022 -19,429.85 Bill Pmt -Check 07/08/2022 13871 Caselle, Inc. 50% deposit for account setup and training -9,648.00 Bill Pmt -Check 07/08/2022 13872 City of Arcata June 2022 Utility User Tax -14,113.97 Bill Pmt -Check 07/08/2022 13873 City of Arcata June 2022 Excessive Energy Use Tax -3,524.89 Bill Pmt -Check 07/08/2022 13874 Hilson, D. Mileage reimbursement - June 2022 -43.30 Bill Pmt -Check 07/08/2022 13875 HireRight Background Check: new hires -206.20 Bill Pmt -Check 07/08/2022 13876 Humboldt Bay Coffee Co. Office Coffee -43.25 Bill Pmt -Check 07/08/2022 13877 Mission Uniform & Linen JULY mat service -8.47 Bill Pmt -Check 07/08/2022 13878 New Mexico Mutual NM worker's comp insurance binder -644.00 Bill Pmt -Check 07/08/2022 13879 North Coast Employer Advisory Council Membership Dues - Jul'22 -Jun'23 -40.00 Bill Pmt -Check 07/08/2022 13880 North Coast Journal Job postings -454.00 Bill Pmt -Check 07/08/2022 13881 NYLEX.net, Inc. Onsite network support services - July -3,200.00 Bill Pmt -Check 07/08/2022 13882 PG&E EV Account EV stations 5/16-6/13/2022 -1,037.62 Bill Pmt -Check 07/08/2022 13883 Pierson Building Center Safety - gloves -17.35 Bill Pmt -Check 07/08/2022 13884 Ray Morgan Company Printer Charges: 6/6-7/5/22 -115.32 Bill Pmt -Check 07/08/2022 13885 Russ Cole RCAM Grand Opening - PA system & sound -850.00 Bill Pmt -Check 07/08/2022 13886 Scrapper's Edge Printing services -50.57 Bill Pmt -Check 07/08/2022 13887 Suddenlink Communications Phone & Internet access - 6/28 - 7/27/2022 -1,098.99 Bill Pmt -Check 07/08/2022 13888 Times Printing Company Printing Services and postage -13,318.52 Bill Pmt -Check 07/08/2022 13889 Frontier Energy, Inc. PA Program Consulting - June 2022 -1,663.75 Check 07/08/2022 13890 VISA June 2022 Statement 5/24/2022 - 6/21/2022 -6,628.76 Liability Check 07/08/2022 13891 Umpqua Bank Health savings account contributions -297.44 Bill Pmt -Check 07/08/2022 13892 Blue Lake Rancheria Loan interest July 2022 -13,333.33 Paycheck 07/08/2022 ACH Employees Payroll -70,341.67
Bill Pmt -Check 07/13/2022 ACH Humboldt Sawmill Co. April 2022 Electricity -10,000.00 Bill Pmt -Check 07/14/2022 ACH Sterling Administration FSA Healthcare and Dependent Care Funding - 50% 2022. -2,625.00 Check 07/20/2022 Debit Umpqua Bank Service Charge -181.64 Liability Check 07/21/2022 ACH Newport Group Deferred compensation contributions -16,489.54 Check 07/22/2022 Debit Umpqua Bank Service Charge -117.50 Check 07/22/2022 Debit Umpqua Bank Service Charge -18.57 Bill Pmt -Check 07/22/2022 ACH CA Dept. of Tax & Fee Administration Electrical Energy Surcharge Return 31-0003366 Q2 2022 -44,770.00 Bill Pmt -Check 07/24/2022 ACH CalCCA Quarterly membership dues -31,577.37 Bill Pmt -Check 07/24/2022 ACH Keenan Medical insurance premiums - July & August -52,588.11 Bill Pmt -Check 07/24/2022 ACH CalPine Corporation Calpine June 2022 Costs -61,677.12 Bill Pmt -Check 07/24/2022 ACH Humboldt Sawmill Co. June 2022 Electricity -664,252.64 Bill Pmt -Check 07/24/2022 ACH Leapfrog Energy June 2022 RA -36,740.00 Bill Pmt -Check 07/24/2022 ACH Snow Mountain Hydro, LLC June 2022 Electricity -8,494.37 Liability Check 07/25/2022 E-pay EDD Taxes -6,656.15
Liability Check 07/25/2022 E-pay Internal Revenue Service Taxes -30,032.98 Liability Check 07/25/2022 E-pay EDD Taxes -5.75
Check 07/25/2022 13893 CCE Customer Heat Pump Rebate #DS-R-220719-0424 -800.00 Check 07/25/2022 13894 CCE Customer PA Equipment Rebate - Res #DS-R-220603-0343 -258.00 Check 07/25/2022 13895 CCE Customer Heat Pump Rebate #DS-R-220719-0422 -800.00 Check 07/25/2022 13896 NGI, Inc. PA install - Nilsen Company - #DI-NR-2200404-201 -1,174.76 Check 07/25/2022 13897 CCE Customer Heat Pump Rebate #DS-R-220719-0423 -975.00 Check 07/25/2022 13898 CCE Customer EV Rebate #: EV28 -1,000.00
9 Accrual Basis Redwood Coast Energy Authority
Disbursements Report
As of July 31, 2022
Type Date Num Name Memo Amount
Check 07/25/2022 13899 CCE Customer Heat Pump Rebate #DS-R-220719-0420 -2,050.00 Check 07/25/2022 13900 CCE Customer PA equipment rebate - #DS-R-220721-0431 -940.00 Bill Pmt -Check 07/25/2022 13901 Aiqueous, LLC May & June consultant expenses -10,050.00 Bill Pmt -Check 07/25/2022 13902 Ameritas - Dental #010-055098-00001 August 2022 -1,912.40 Bill Pmt -Check 07/25/2022 13903 Ameritas - Vision 010-055098-00002 August 2022 -426.52 Bill Pmt -Check 07/25/2022 13904 Arcata Technology Center Site Host Reimbursement 4/1 - 6/30/2022 -393.62 Bill Pmt -Check 07/25/2022 13905 AT&T RCAM charges: 7/1 - 7/31/2022 -921.24 Bill Pmt -Check 07/25/2022 13906 B&B Portable Toilets Sanitary services for RCAM event -512.83 Bill Pmt -Check 07/25/2022 13907 Bithell, M. Mileage reimbursement - June 2022 -198.66 Bill Pmt -Check 07/25/2022 13908 Blue Lake Rancheria Site Host Reimbursement 4/1 - 6/30/2022 -54.76 Bill Pmt -Check 07/25/2022 13909 Blue Lake Rancheria Loan repayment August 2022 -13,777.78 Bill Pmt -Check 07/25/2022 13910 Boone, J. Purchase reimbursement - ribbon for RCAM event -8.73 Bill Pmt -Check 07/25/2022 13911 City of Arcata Site Host Reimbursement 4/1 - 6/30/2022 -402.60 Bill Pmt -Check 07/25/2022 13912 City of Blue Lake Site Host Reimbursement 4/1 - 6/30/2022 -233.49 Bill Pmt -Check 07/25/2022 13913 City of Eureka-Water Water service, 5/25- 6/28/22 -186.41 Bill Pmt -Check 07/25/2022 13914 City of Eureka - REVNet Site Host Reimbursement 4/1 - 6/30/2022 -812.58 Bill Pmt -Check 07/25/2022 13915 City of Trinidad Site Host Reimbursement 4/1 - 6/30/2022 -377.00 Bill Pmt -Check 07/25/2022 13916 Colonial Life Colonial Life Premiums July 2022 -1,489.40 Bill Pmt -Check 07/25/2022 13917 County of Humboldt - Div. of Env. Health RCAM Hazardous Waste fees -454.08 Bill Pmt -Check 07/25/2022 13918 David L. Moonie & Co., LLP Accounting consulting - June 2022 -1,968.00 Bill Pmt -Check 07/25/2022 13919 Developed Employment Services, LLC. Facilities maintenance work -58.70 Bill Pmt -Check 07/25/2022 13920 Diamond, Nancy June legal expenses -13,100.00 Bill Pmt -Check 07/25/2022 13921 Donald Dame Professional Services June 2022 -262.50 Bill Pmt -Check 07/25/2022 13922 Means, M. March-June mileage reimbursement -76.95 Bill Pmt -Check 07/25/2022 13923 Mission Uniform & Linen JULY mat service -8.47 Bill Pmt -Check 07/25/2022 13924 North Coast Cleaning June monthly cleaning service -480.00 Bill Pmt -Check 07/25/2022 13925 North Coast Journal July job postings -454.00 Bill Pmt -Check 07/25/2022 13926 North Coast Unified Air Quality Site Host Reimbursement 4/1 - 6/30/2022 -461.30 Bill Pmt -Check 07/25/2022 13927 NYLEX.net, Inc. Onsite network support services - August -3,200.00 Bill Pmt -Check 07/25/2022 13928 Open Door Site Host Reimbursement 4/1 - 6/30/2022 -347.62 Bill Pmt -Check 07/25/2022 13929 PG&E CCA June 2022 CCE Charges -22,232.35 Bill Pmt -Check 07/25/2022 13930 PG&E Utility Account 6/14-7/14/22 utilities -860.03 Bill Pmt -Check 07/25/2022 13931 Redwood Community Radio Radio underwriting - Q3 2022 -780.00 Bill Pmt -Check 07/25/2022 13932 Scrapper's Edge Wide Format Priting -64.54 Bill Pmt -Check 07/25/2022 13933 St. Joseph Hospital Site Host Reimbursement 4/1 - 6/30/2022 -1,223.93 Bill Pmt -Check 07/25/2022 13934 Verizon Wireless Tablet/cell service for staff - 5/29 - 6/28/2022 -1,329.95 Bill Pmt -Check 07/25/2022 13935 Winzler, John Office Lease - August 2022 -7,132.00 Bill Pmt -Check 07/25/2022 13936 WREGIS Retired RECs - July 2022 -649.72 Bill Pmt -Check 07/25/2022 13937 Boone, J. Mileage reimbursement - June 2022 -32.20 Paycheck 07/25/2022 ACH Employees Payroll -70,517.49
Liability Check 07/27/2022 E-pay Arizona Department of Revenue 9515070 6 QB Tracking # -196499622 -106.60 Liability Check 07/27/2022 E-pay Arizona Department of Revenue 743104616 QB Tracking # -195985622 -174.90 Paycheck 07/29/2022 ACH Employee Final paycheck -4,556.76 TOTAL -1,354,156.93
10 Redwood Coast Energy Authority
Profit & Loss Budget vs. Actual
July 2022
Jul 22 Budget % of Budget
Ordinary Income/Expense
Income
5 REVENUE EARNED
5000 · Revenue - government agencies 0.00 1,101,031.00 0.0% Total 5100 · Revenue - program related sales 2,490.50 30,400.00 8.19% Total 5400 · Revenue-nongovernment agencies 15,533.00 489,124.00 3.18% Total 5500 · Revenue - Electricity Sales 6,301,417.88 93,848,684.00 6.71% Total 5 REVENUE EARNED 6,319,441.38 95,469,239.00 6.62% Total Income 6,319,441.38 95,469,239.00 6.62%
Gross Profit 6,319,441.38 95,469,239.00 6.62%
Expense
Total 6 WHOLESALE POWER SUPPLY 4,051,458.77 76,236,276.00 5.31% Total 7 PERSONNEL EXPENSES 315,376.89 4,071,684.00 7.75% Total 8.1 FACILITIES AND OPERATIONS 52,193.47 801,816.00 6.51% Total 8.2 COMMUNICATIONS AND OUTREACH 3,012.02 177,004.00 1.7%
8.4 PROFESSIONAL & PROGRAM SRVS
8400 · Regulatory 29,465.41 180,000.00 16.37%
8410 · Contracts - Program Related Ser 1,057.25 290,000.00 0.37% 8420 · Accounting 1,748.00 87,455.00 2.0%
8430 · Legal 6,000.00 180,000.00 3.33%
8450 · Wholesale Services - TEA 58,184.41 654,984.00 8.88% 8460 · Procurement Credit - TEA 56,800.39 690,545.00 8.23% 8470 · Data Management - Calpine 61,597.44 737,532.00 8.35% Total 8.4 PROFESSIONAL & PROGRAM SRVS 214,852.90 2,820,516.00 7.62% Total 8.5 PROGRAM EXPENSES 60,911.13 638,100.00 9.55%
Total 8.6 INCENTIVES & REBATES 11,448.79 477,823.00 2.4% Total 9 NON OPERATING COSTS 13,838.67 2,246,020.00 0.62% Total Expense 4,723,092.64 87,469,239.00 5.4%
Net Ordinary Income 1,596,348.74 8,000,000.00 19.95%
Net Income 1,596,348.74 8,000,000.00 19.95%
11 Redwood Coast Energy Authority
Balance Sheet
As of July 31, 2022
Jul 31, 22
ASSETS
Current Assets
Checking/Savings
1010 · Petty Cash 414.35
1050 · GRANTS & DONATIONS 3840 15,995.51
1060 · Umpqua Checking Acct 0560 -9,343.62
1071 · Umpqua Deposit Cntrol Acct 8215 3,605,309.73
1075 · Umpqua Reserve Account 2300 1,099,923.52
1076 · First Republic Bank - 4999 62,263.94
8413 · COUNTY TREASURY 3839 5,329.01
Total Checking/Savings 4,779,892.44
Total Accounts Receivable 71,572.06
Other Current Assets
1101 · Allowance for Doubtful Accounts -2,502,526.62
1103 · Accounts Receivable-Other 13,286,387.27
1120 · Inventory Asset 21,715.00
1202 · Prepaid Expenses -16,743.22
1205 · Prepaid Insurance 32,856.29
1499 · Undeposited Funds 1,403.00
Total Other Current Assets 10,823,091.72
Total Current Assets 15,674,556.22
Total Fixed Assets 8,678,528.16
Other Assets
1700 · Retained Deposits 4,291,600.00
Total Other Assets 4,291,600.00
TOTAL ASSETS 28,644,684.38
LIABILITIES & EQUITY
Liabilities
Current Liabilities
Total Accounts Payable 4,487,992.12
Total Credit Cards 9,705.25
Other Current Liabilities
2002 · Deposits Refundable 275,715.01
2013 · Unearned Revenue - PA 2020-2023 988,348.00
Total 2050 · Current Loans 6,000,000.00
Total 2100 · Payroll Liabilities 179,926.21
Total Other Current Liabilities 7,443,989.22
Total Current Liabilities 11,941,686.59
Long Term Liabilities
Total 2700 · Long-Term Debt 6,287,592.00
Total Long Term Liabilities 6,287,592.00
Total Liabilities 18,229,278.59
Equity
2320 · Investment in Capital Assets 215,489.00
3900 · Fund Balance 8,603,568.05
Net Income 1,596,348.74
Total Equity 10,415,405.79
TOTAL LIABILITIES & EQUITY 28,644,684.38
12
STAFF REPORT
Agenda Item # 3.4
AGENDA DATE: September 22, 2022
TO: Board of Directors
PREPARED BY: Eileen Verbeck, Deputy Executive Director
SUBJECT: Virtual Board and CAC Meeting Authorization
BACKGROUND
In response to the COVID-19 public health emergency and in compliance with emergency Brown Act meeting law changes, the RCEA Board of Directors, Community Advisory Committee and the subcommittees of those bodies have been meeting online via the Zoom teleconference platform since April 2020. In September 2021 Governor Newsom signed AB 361 into law. This bill authorized legislative bodies to meet virtually provided there is a state of emergency, and either 1) state or local officials have imposed or recommended measures to promote social distancing, or 2) the legislative body determines by majority vote that meeting in person would present imminent risks to the health and safety of attendees.
To date, Governor Newsom’s March 4, 2020, COVID-19 State of Emergency is still in effect.
According to the Centers for Disease Control and Prevention, COVID-19 transmission in Humboldt County is at a medium level. The California Department of Public Health especially recommends masking in indoor settings with unvaccinated persons or with persons whose vaccination status is unknown, and in any public place for people who are older or with medical conditions that put them at higher risk of severe COVID illness. In addition, when COVID-19 community levels are medium or high the Centers for Disease Control recommend wearing a high-quality mask when indoors in public if you are at high risk of getting very sick and when in social or household contact with someone at high risk for getting very sick.
SUMMARY
At its June 2022 meeting, this Board decided to continue meeting virtually until the number of COVID-19 cases locally begin trending downward. At the time of agenda publication, local COVID case counts are fluctuating and rose from low to medium level in the past month.
In order to continue virtual meetings and for Board directors and CAC members to participate without making their remote meeting locations publicly accessible, the Board must adopt or extend AB 361 resolutions every 30 days.
ALIGNMENT WITH RCEA’S STRATEGIC PLAN
N/A – Operations.
13
EQUITY IMPACTS
N/A. Staff recommends taking measures to reduce health risks to vulnerable populations.
FINANCIAL IMPACT
Annual teleconferencing subscription costs have been included in the Fiscal Year 2022-23 budget.
STAFF RECOMMENDATION
Extend Resolution No. 2022-6 Ratifying Governor Newsom’s March 4, 2020, State of Emergency Proclamation and Authorizing Remote Teleconference Meetings of RCEA’s Legislative Bodies, for the period September 22, 2022, through October 21, 2022, pursuant to Brown Act revisions of AB 361.
ATTACHMENTS
1. Resolution No. 2022-6 Ratifying Governor Newsom’s March 4, 2020, State of Emergency Proclamation and Authorizing Remote Teleconference Meetings of RCEA’s Legislative Bodies, for the period June 27, 2022, through July 27, 2022, pursuant to Brown Act revisions of AB 361, adopted June 23, 2022.
14
RESOLUTION NO. 2022-6
A RESOLUTION OF THE BOARD OF DIRECTORS
OF THE REDWOOD COAST ENERGY AUTHORITY
RATIFYING THE PROCLAMATION OF A STATE OF EMERGENCY
BY GOVERNOR GAVIN NEWSOM ON MARCH 4, 2020,
AND AUTHORIZING REMOTE TELECONFERENCE MEETINGS
OF THE LEGISLATIVE BODIES OF REDWOOD COAST ENERGY AUTHORITY FOR THE PERIOD JUNE 27, 2022, THROUGH JULY 27, 2022,
PURSUANT TO BROWN ACT PROVISIONS
WHEREAS, the Redwood Coast Energy Authority (RCEA) is committed to preserving and nurturing public access and participation in meetings of the Board of Directors; and WHEREAS, all meetings of RCEA’s legislative bodies are open and public, as required by the Ralph M.
Brown Act (Cal. Gov. Code 54950 – 54963), so that any member of the public may attend, participate, and watch RCEA’s legislative bodies conduct their business; and WHEREAS, the Brown Act, Government Code section 54953(e), makes provisions for remote teleconferencing participation in meetings by members of a legislative body, without compliance with the requirements of Government Code section 54953(b)(3), subject to the existence of certain conditions; and WHEREAS, a required condition is that a state of emergency is declared by the Governor pursuant to Government Code section 8625, proclaiming the existence of conditions of disaster or of extreme peril to the safety of persons and property within the state caused by conditions as described in Government Code section 8558; and
WHEREAS, a proclamation is made when there is an actual incident, threat of disaster, or extreme peril to the safety of persons and property within the jurisdictions that are within RCEA’s boundaries, caused by natural, technological, or human-caused disasters; and WHEREAS, it is further required that state or local officials have imposed or recommended measures to promote social distancing, or, the legislative body has determined that meeting in person would present imminent risks to the health and safety of attendees; and WHEREAS, such conditions now exist in Humboldt County, specifically, Governor Newsom’s Proclamation of a State of Emergency of March 4, 2020, remains in effect; and WHEREAS, the Humboldt County Department of Health and Human Services recommends practicing physical distancing at meetings of legislative bodies; and WHEREAS, COVID-19 public health emergency and increased risk of infection has caused, and will continue to cause, conditions of peril to the safety of persons within Humboldt County that are likely to be beyond the control of services, personnel, equipment, and facilities of RCEA, and desires to ratify the proclamation of state of emergency by the Governor of the State of California; and WHEREAS, as a consequence of the emergency, the Board of Directors does hereby find that the legislative bodies of RCEA shall conduct their meetings without compliance with paragraph (3) of subdivision (b) of Government Code section 54953, as authorized by subdivision (e) of section 54953, and that such legislative bodies shall comply with the requirements to provide the public with access to the meetings as prescribed in paragraph (2) of subdivision (e) of section 54953; and DocuSign Envelope ID: 1779DE0A-F481-4A12-AFEC-C13FE4DBA77D 15
WHEREAS, public access and participation in meetings of RCEA’s legislative bodies shall be provided via online video conferencing software which shall also allow for public participation and real-time public comment opportunity by telephone.
NOW, THEREFORE, THE BOARD OF DIRECTORS OF REDWOOD COAST ENERGY AUTHORITY DOES HEREBY RESOLVE AS FOLLOWS:
Section 1. Recitals. The Recitals set forth above are true and correct and are incorporated into this Resolution by this reference.
Section 2. Ratification of Governor’s Proclamation of a State of Emergency. The Board hereby ratifies the Governor of the State of California’s Proclamation of State of Emergency, effective as of its issuance date of March 4, 2020.
Section 3. Remote Teleconference Meetings. The staff and legislative bodies of Redwood Coast Energy Authority, including but not limited to the Board of Directors and its subcommittees, and the Community Advisory Committee and its subcommittees, are hereby authorized and directed to take all actions necessary to carry out the intent and purpose of this Resolution including conducting open and public meetings in accordance with Government Code section 54953(e) and other applicable provisions of the Brown Act.
Section 4. Effective Date of Resolution. This Resolution shall take effect immediately upon its adoption and shall be effective for 30 days or until this Resolution is extended by a majority vote of the Board of Directors in accordance with Section 5 of this Resolution.
Section 5. Extension by Motion. The Board of Directors may extend the application of this Resolution by motion and majority vote by up to 30 days at a time, provided that it makes all necessary findings consistent with and pursuant to the requirements of Section 54953(e)(3).
Adopted this 23rd day of June 2022.
ATTEST:
Stephen Avis, RCEA Board Chair Lori Taketa, Clerk of the Board Date: _________________________ Date: ________________________ DocuSign Envelope ID: 1779DE0A-F481-4A12-AFEC-C13FE4DBA77D 6/30/2022 7/14/2022
16
CLERK'S CERTIFICATE
I hereby certify that the foregoing is a true and correct copy of Resolution 2022-6 passed and adopted at a regular meeting of the Redwood Coast Energy Authority, County of Humboldt, State of California, held on the 23rd day of June 2022, by the following vote:
AYES: Avis, Bauer, Bohn, Curran, Losey, Schaefer, Tuttle, Wilson, Woo.
NOES: None.
ABSENT: None.
ABSTENTIONS: None.
Clerk of the Board, Redwood Coast Energy Authority
DocuSign Envelope ID: 1779DE0A-F481-4A12-AFEC-C13FE4DBA77D 17
STAFF REPORT
Agenda Item # 5.1
AGENDA DATE: September 22, 2022
TO: Board of Directors
PREPARED BY: Jocelyn Gwynn, Senior Power Resources Manager Richard Engel, Director of Power Resources
SUBJECT: Foster Clean Power A Solar + Storage Agreement
BACKGROUND
In September 2021, RCEA launched a Request for Offers (RFO) for Long-term Reliability Resources in response to the California Public Utilities Commission’s (CPUC) June 2021 Mid-Term Reliability (MTR) Decision 21-06-035 to address reliability needs of the state’s grid in the 2023-2026 term. The Decision requires each load-serving entity (LSE) in California, including RCEA, to procure its allocated share of incremental resource adequacy (RA) capacity. RCEA is obligated to purchase RA on an annual and monthly basis as part of the state’s reliability program to ensure the California Independent System Operator has sufficient capacity to maintain reliable grid operations at all times. An additional requirement that the MTR Decision places on LSEs is that a portion of that RA capacity must come from new resources to replace retiring gas and nuclear facilities in the coming years.
At its January 2022 meeting, the Board approved shortlisting three projects under the RFO, a battery storage project and two solar plus battery storage projects, all three of which will be local to the Humboldt Bay area. The Board having approved a contract for the Fairhaven battery storage project in June, staff are now bringing the second of these contracts to the Board for approval. The Power Purchase Agreement with Foster Clean Power A LLC was reviewed and approved by outside counsel and RCEA general counsel. Staff are providing an update on the third project as a separate agenda item at this meeting.
SUMMARY
The Foster Clean Power project is a hybrid 3 MW solar plus 1.25 MW battery storage system that is being developed by Renewable America on land adjacent to Foster Avenue in Arcata. They have an executed lease option agreement with the private landowner for the term of the Power Purchase Agreement (PPA) and a signed interconnection agreement with PG&E. The developer has been transparent with staff that after the project is built, they plan to assign the PPA, along with agreements for other projects they are developing, to Excelsior Energy Capital, an independent North American renewable energy investor.
The Foster project was originally shortlisted with the expectation that it could begin operation during summer 2023, thus allowing RCEA to count it toward our first MTR compliance milestone. 18
However, due to uncertainty in the solar equipment supply chain and in the timing of securing a deliverability allocation from CAISO (which is required for the project to provide RA), the developer has revised the schedule to bring the project online in Q2 2023 and to begin delivering RA to RCEA in Q2 2024. Despite the schedule change, the project still has compliance value to RCEA, given our 2024 and 2025 MTR obligations. If the project is delayed, CPUC rules and contract terms allow that RCEA can procure, or the developer can supply, short-term replacement capacity to meet our compliance obligation. If the project does not secure a deliverability allocation by 2025, then the contract price will be reduced to reflect the reduction in value to RCEA. Aside from RA compliance, the project will also deliver energy, renewable energy certificates and local development benefits to RCEA, including contributing to our local solar procurement goal.
ALIGNMENT WITH RCEA’S STRATEGIC PLAN
By continuing to build RCEA’s portfolio of long-term, local renewable and storage resources, this project contributes to many Strategic Plan goals:
• 4.1.1 Maximize the Use of Local Renewable Energy to the Extent Technically and Economically Feasible and Prudent.
• 4.1.2 Minimize Greenhouse Gas Emissions Associated with RCEA’s CCE Program. • 4.1.4 Maximize Renewable Energy Content of RCEA’s CCE Program. • 4.1.5 Ensure Diversity in Local Sources
• 4.1.7.2 Develop Distributed Generation.
• 4.1.8.1 Support Utility Scale Solar Energy Development. • 4.1.8.2 Procure Local Solar Energy.
EQUITY IMPACTS
Renewable America is not listed in the CPUC’s Supplier Diversity Clearinghouse as a diverse business enterprise. They are working with GRID Alternatives on workforce development opportunities through this and their other projects, including potential community benefit or project labor agreements.
FINANCIAL IMPACT
Initial analysis by The Energy Authority shows that the expected value of the energy, RECs and RA from Foster Clean Power is at parity with the contract cost over the term of the agreement.
These costs and revenues are accounted for in RCEA’s financial model and will be incorporated into the budget starting in fiscal year 2023-2024. This project will also bring value to RCEA’s long-term portfolio as a hedge against price volatility risk for all three products.
STAFF RECOMMENDATION
Approve Power Purchase Agreement with Foster Clean Power A LLC and authorize the Executive Director to execute all applicable documents.
ATTACHMENTS
Power Purchase Agreement with Foster Clean Power A LLC
19 Foster Clean Power A
Solar + Storage PPA
Presentation to RCEA Board of Directors
September 22, 2022
Foster Clean Power A
• 3 MW solar photovoltaic generator paired with 1.25 MW / 5 MWh battery energy storage system
• Project site is off Foster Avenue in Arcata
• Developer is Renewable America, long-term owner will be Excelsior Energy Capital
• 20-year power purchase agreement
• Commercial operation expected June 2023, guaranteed Dec 2023 Contract Milestone Schedule
Milestone Date/Expected Date for Completion
Demonstrate Site Control 07/20/2021
Execute Interconnection Agreement 01/18/2022
Obtain Conditional Use Permit 12/31/2022
Expected Construction Start Date 03/01/2023
Procure Major Equipment 03/31/2023
Expected Commercial Operation Date 06/30/2023
Expected Full Capacity Deliverability Status Date 03/31/2024 RA Guarantee Date 03/31/2025
STAFF REPORT
Agenda Item # 6.1
AGENDA DATE: September 22, 2022
TO: Board of Directors
PREPARED BY: Dana Boudreau, Director of Infrastructure Planning and Operations Lexie Perez, Contracts and Grants Manager
SUBJECT: Rural Electric Vehicle Charging CEC Grant
BACKGROUND
On December 14, 2021, the California Energy Commission (CEC) released a Grant Solicitation entitled “Rural Electric Vehicle (REV) Charging” under the Clean Transportation Program. This grant solicitation was an offer to demonstrate replicable and scalable business and technology models for deployment of public electric vehicle (EV) charging infrastructure capable of maximizing access and EV travel for rural residents.
In March 2022, RCEA submitted a grant application titled “North Coast Plug-In Electric Vehicle Charging Network Phase 2,” requesting $700,000. The grant requires a minimum match requirement of 20 percent, or $175,000 for this submission, resulting in a total project budget of $875,000. In June 2022, RCEA received a Notice of Proposed Award, and final approval is expected during either the November or December CEC business meeting. Staff are now bringing this contract to the Board for approval.
SUMMARY
Based on RCEA strategic goals and existing electric vehicle charging network, staff recognized this solicitation as an ideal opportunity to expand our network. Based on our ongoing experience with electric vehicle charging, microgrids, and PSPS events, staff also envisioned an opportunity to integrate electric vehicle charging with future renewable energy and storage at key locations in our region.
As resiliency funding becomes available, future initiatives will be pursued to expand sites with renewable energy generation and storage, further expanding charging and vehicle-to-grid capabilities during normal conditions, and essential service delivery during emergencies. These concepts are already proven through our partnership with the Blue Lake Rancheria and ongoing efforts at the Redwood Coast Airport Microgrid. The eventual goal is to leverage the ability of EV infrastructure to stabilize and expand critical services in times of increasing uncertainty.
The goal of this project is to install ten Level 2 electric vehicle charging sites at strategic community hub locations around Humboldt County. The expected start date to implement this 20
project is January 2023, with a deadline of March 2028. See table below for a list of proposed project sites.
Table: list of proposed EV charging sites
Orleans Volunteer Fire Department, Orleans Rohner Park, Fortuna Azalea Hall, McKinleyville Providence Redwood Memorial Hospital, Fortuna
Mad River Community Hospital, Arcata Redwoods Rural Health Center, Redway Carlson Park, Arcata Jerold Phelps Community Hospital,
Garberville
Sequoia Park, Eureka
Pending Board approval of this grant, staff will engage the Board during the implementation of this project for authorization to solicit and award contracts to subcontractors for the required engineering and construction work.
ALIGNMENT WITH RCEA’S STRATEGIC PLAN
By expanding our existing EV charging network and enabling future resiliency work at locations across the county, this project contributes to these Strategic Plan goals:
• 2.1.5 Integrate Distributed Energy Resources.
• 3.2.2 Promote Advanced Fuels.
• 3.2.3 Support Electric Vehicle Adoption.
• 3.3.1 Develop Transportation Electrification Infrastructure. • 3.3.4 Promote Vehicle-to-Grid Connection.
EQUITY IMPACTS
The grant solicitation required that at least 50 percent of project costs be spent on low-income or disadvantaged communities or both. RCEA’s “North Coast Plug-In Electric Vehicle Charging Network Phase 2” project will support switching from gasoline vehicles to EVs, which will reduce criteria air pollutants and greenhouse gas (GHG) emissions in California. All RCEA project sites are within the AB 1550 Low-income Communities designated area, and an August 2022 California Energy Commission staff report “Localized Health Impacts Report” lists our project sites as meeting one or more Environmental Justice indicators for age, poverty, or unemployment.
FINANCIAL IMPACT
RCEA received a Notice of Proposed Award for the North Coast Plug-In Electric Vehicle Charging Network Phase 2 Project. The total project cost is $875,000 and includes $700,000 in CEC grant funds and $175,000 in RCEA matching funds. Project costs include electric vehicle charging equipment, vendor costs for site preparation and installation, and RCEA staff time for grant administration and planning.
21
The project implementation timeline is from January 2023 to March 2028. Grant expenses and associated revenue were not included in the FY 22-23 adopted budget. A budget adjustment will be prepared to account for any additional revenue and related expenses that will be incurred this fiscal year. With an implementation timeline that spans up to six fiscal years, there is flexibility as to when the $175,000 general funds can be included in budgets and incurred.
The new charging stations will be capital assets owned and operated by RCEA and will generate revenue from the sale of electricity to EV drivers.
STAFF RECOMMENDATION
Approve Accepting CEC Rural Electric Vehicle Charging Grant in the amount of $700,000 and authorize $175,000 in RCEA match funds for a total project cost of $875,000 and Authorize the Executive Director to Execute the Grant Agreement and Any Associated Documents Necessary to Secure the Grant following review and approval by RCEA General Counsel.
ATTACHMENTS
Draft Scope of Work for North Coast Plug-In Electric Vehicle Charging Network Phase 2 project EV Charging Network Phase 2 Proposal Budget
22 Redwood Coast Energy Authority
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Attachment 02 - Scope of Work REV Charging
Exhibit A
SCOPE OF WORK
TECHNICAL TASK LIST
Task # CPR Task Name
1 Administration
2 Charging Network Final Planning and Design
3 X Charging Network Construction and Start-Up Operations 4 Data Collection and Analysis
5 Project Fact Sheet
6 Operations and Maintenance
KEY NAME LIST
Task # Key Personnel Key Subcontractor(s) Key Partner(s) 1 Matthew Marshall –
RCEA, Dana
Boudreau – RCEA
2 Matthew Marshall –
RCEA, Dana
Boudreau – RCEA
Orleans Volunteer Fire
Department;
McKinleyville Community
Services District;
City of Arcata;
Mad River Community
Hospital;
City of Eureka;
College of the Redwoods;
City of Fortuna;
Providence Redwood
Memorial Hospital;
Redwoods Rural Health
Center;
Southern Humboldt
Community Healthcare
District
3 Matthew Marshall –
RCEA, Dana
Boudreau – RCEA
Orleans Volunteer Fire
Department;
McKinleyville Community
Services District;
City of Arcata;
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Attachment 02 - Scope of Work REV Charging
Task # Key Personnel Key Subcontractor(s) Key Partner(s) Mad River Community
Hospital;
City of Eureka;
College of the Redwoods;
City of Fortuna;
Providence Redwood
Memorial Hospital;
Redwoods Rural Health
Center;
Southern Humboldt
Community Healthcare
District
4 Matthew Marshall –
RCEA, Dana
Boudreau – RCEA
5 Matthew Marshall –
RCEA, Dana
Boudreau – RCEA
6 Matthew Marshall –
RCEA, Dana
Boudreau – RCEA
GLOSSARY
Specific terms and acronyms used throughout this scope of work are defined as follows:
Term/
Acronym Definition
CAM Commission Agreement Manager
CAO Commission Agreement Officer
CEC California Energy Commission
CTP Clean Transportation Program
CPR Critical Project Review
FTD Fuels and Transportation Division
Recipient An applicant awarded a grant under a CEC solicitation RCEA Redwood Coast Energy Authority
PEV Plug-In Electric Vehicle
EVSE Electric Vehicle Supply Equipment
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Attachment 02 - Scope of Work REV Charging
Term/
Acronym Definition
MOU Memorandum of Understanding
PG&E Pacific Gas & Electric Company
Level 1 EVSE Electric Vehicle Chargers that operate on 120 volts and can deliver up to 20 amps of electrical current
Level 2 EVSE Electric Vehicle Chargers that operate on 240 Volts and can deliver up to 80 amps of electric current as specified under the Society of Automotive Engineers Standard J1772.
Level 3 EVSE Electric Vehicle Chargers that operate on industrial power, typically 480 Volts, three phase, and up to 400 amps. These chargers, also referred to as DC fast chargers, rectify alternating current to direct current that is supplied directly to the car’s battery allowing for short charge durations
GHG Greenhouse gases such as carbon dioxide, methane, and nitrous oxide Network North Coast Plug-In Electric Vehicle Charging Network Network
Administrator
The Administrator of the North Coast Plug-In Electric Vehicle Charging Network is the Redwood Coast Energy Authority
Background
The Budget Act of 2021 (AB 128, Ting, Chapter 21, Statutes of 2021, as amended by Senate Bill (SB) 129, Skinner, Chapter 69, Statutes of 2021 and SB 170, Skinner, Chapter 240, Statutes of 2021) appropriated $785,000,000 from the General Fund to support infrastructure deployments and manufacturing projects for zero-emission light-duty and medium- and heavy-duty vehicles.
On December 14, 2021, the CEC released a Grant Solicitation and Application Package entitled “GFO-21-604 – Clean Transportation Program Rural Electric Vehicle (REV) Charging” under the Clean Transportation Program. This competitive grant solicitation was to fund projects that would demonstrate replicable and scalable business and technology models for deployment of electric vehicle (EV) charging infrastructure capable of maximizing access and EV travel for rural residents. In response to GFO-21- 604, the Recipient submitted application #11 which was proposed for funding in the CEC’s Notice of Proposed Awards on June 24, 2022. GFO-21-604 and Recipient’s application are hereby incorporated by reference into this Agreement in their entirety.
In the event of any conflict or inconsistency between the terms of the Solicitation and the terms of the Recipient’s Application, the Solicitation shall control. In the event of any conflict or inconsistency between the Recipient’s Application and the terms of CEC’s Award, CEC’s Award shall control. Similarly, in the event of any conflict or inconsistency between the terms of this Agreement and the Recipient’s Application, the terms of this Agreement shall control.
25 Redwood Coast Energy Authority
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Attachment 02 - Scope of Work REV Charging
Problem Statement:
Range anxiety remains a perception issue in rural settings. Rural populations are typically diffuse, resulting in longer distances to reach work, services, and home. In rural settings, parking areas are typically small, and sites often defer improvements to avoid triggering ADA and other code requirement costs. Electrical service is often distant from building entrances, distribution systems are often old and at full capacity, and transformers often require upgrades to handle additional onsite loads and can significantly increase total project costs. Rural sites typically have limited infrastructure available to support EV charging and to provide temporary shelter and deliver services during emergencies.
Goals of the Agreement:
The goal of this Agreement is to increase rural charging access and build community resilience by installing 10 Level 2 electric vehicle charging sites (total of 32 ports) at strategic community hub locations around Humboldt County. The project will expand the charging station network established by RCEA in 2016 using funds from ARV-13-029, focusing where possible on high-risk communities in remote locations that would otherwise be unaddressed by private networks or commercial organizations.
Objectives of the Agreement:
The objectives of this Agreement are to:
• Select EVSE manufacturer and model compatible with existing charging network and site requirements.
• Finalize and provide civil and electrical engineering documentation for each site. • Conduct construction project bidding, summarize bid results, and issue notice of award and notice to proceed.
• Administer and observe construction. Inform and educate the community about the availability of stations and educate residents and business owners on the benefits of electric vehicles and EV charging stations. • Collect and analyze charging data.
• Provide a project fact sheet.
TASK 1 ADMINISTRATION
Task 1.1 Attend Kick-off Meeting
The goal of this task is to establish the lines of communication and procedures for implementing this Agreement. The Commission Agreement Manager (CAM) shall designate the date and location of this meeting and provide an agenda to the Recipient prior to the meeting.
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Attachment 02 - Scope of Work REV Charging
The Recipient shall:
• Attend a “Kick-Off” meeting with the CAM, the Commission Agreement Officer (CAO), and a representative of the California Energy Commission (CEC) Accounting Office. The Recipient shall bring their Project Manager, Agreement Administrator, Accounting Officer, and any others determined necessary by the Recipient or specifically requested by the CAM to this meeting.
• Provide a written statement of project activities that have occurred after the notice of proposed awards but prior to the execution of the agreement using match funds. If none, provide a statement that no work has been completed using match funds prior to the execution of the agreement. All pre-execution match expenditures must conform to the requirements in the Terms and Conditions of this Agreement.
• Discuss the following administrative and technical aspects of this Agreement:
o Agreement Terms and Conditions
o Critical Project Review (Task 1.2)
o Match fund documentation (Task 1.7) No reimbursable work may be done until this documentation is in place.
o Permit documentation (Task 1.8)
o Subcontracts needed to carry out project (Task 1.9)
o The CAM’s expectations for accomplishing tasks described in the Scope of Work
o An updated Schedule of Products and Due Dates
o Monthly Calls (Task 1.4)
o Quarterly Progress Reports (Tasks 1.5)
o Technical Products (Product Guidelines located in Section 5 of the Terms and Conditions)
o Final Report (Task 1.6)
Recipient Products:
• Updated Schedule of Products
• Updated List of Match Funds
• Updated List of Permits
• Written Statement of Match Share Activities
Commission Agreement Manager Product:
• Kick-Off Meeting Agenda
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Attachment 02 - Scope of Work REV Charging
Task 1.2 Critical Project Review (CPR) Meetings
CPRs provide the opportunity for frank discussions between the CEC and the Recipient.
The goal of this task is to determine if the project should continue to receive CEC funding to complete this Agreement and to identify any needed modifications to the tasks, products, schedule, or budget.
The CAM may schedule CPR meetings as necessary, and meeting costs will be borne by the Recipient.
Meeting participants include the CAM and the Recipient and may include the CAO, the Fuels and Transportation Division (FTD) program lead, other CEC staff and Management as well as other individuals selected by the CAM to provide support to the CEC.
The CAM shall:
• Determine the location, date, and time of each CPR meeting with the Recipient. These meetings generally take place at the CEC, but they may take place at another location or remotely.
• Send the Recipient the agenda and a list of expected participants in advance of each CPR. If applicable, the agenda shall include a discussion on both match funding and permits.
• Conduct and make a record of each CPR meeting. Prepare a schedule for providing the written determination described below.
• Determine whether to continue the project, and if continuing, whether or not modifications are needed to the tasks, schedule, products, and/or budget for the remainder of the Agreement. Modifications to the Agreement may require a formal amendment (please see section 8 of the Terms and Conditions). If the CAM concludes that satisfactory progress is not being made, this conclusion will be referred to the Lead Commissioner for Transportation for his or her concurrence.
• Provide the Recipient with a written determination in accordance with the schedule. The written response may include a requirement for the Recipient to revise one or more product(s) that were included in the CPR.
The Recipient shall:
• Prepare a CPR Report for each CPR that discusses the progress of the Agreement toward achieving its goals and objectives. This report shall include recommendations and conclusions regarding continued work of the projects. This report shall be submitted along with any other products identified in this scope of work. The Recipient shall submit these documents to the CAM and any other designated reviewers at least 15 working days in advance of each CPR meeting.
• Present the required information at each CPR meeting and participate in a discussion about the Agreement.
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Attachment 02 - Scope of Work REV Charging
CAM Products:
• Agenda and a list of expected participants
• Schedule for written determination
• Written determination
Recipient Product:
• CPR Report(s)
Task 1.3 Final Meeting
The goal of this task is to closeout this Agreement.
The Recipient shall:
• Meet with CEC staff to present the findings, conclusions, and recommendations. The final meeting must be completed during the closeout of this Agreement.
This meeting will be attended by, at a minimum, the Recipient and the CAM. The technical and administrative aspects of Agreement closeout will be discussed at the meeting, which may be two separate meetings at the discretion of the CAM.
The technical portion of the meeting shall present an assessment of the degree to which project and task goals and objectives were achieved, findings, conclusions, recommended next steps (if any) for the Agreement, and recommendations for improvements. The CAM will determine the appropriate meeting participants.
The administrative portion of the meeting shall be a discussion with the CAM about the following Agreement closeout items:
o What to do with any equipment purchased with CEC funds (options)
o CEC request for specific “generated” data (not already provided in Agreement products)
o Need to document Recipient’s disclosure of “subject inventions” developed under the Agreement
o “Surviving” Agreement provisions
o Final invoicing and release of retention
• Prepare a schedule for completing the closeout activities for this Agreement.
Products:
• Written documentation of meeting agreements
• Schedule for completing closeout activities
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Task 1.4 Monthly Calls
The goal of this task is to have calls at least monthly between CAM and Recipient to verify that satisfactory and continued progress is made towards achieving the objectives of this Agreement on time and within budget.
The objectives of this task are to verbally summarize activities performed during the reporting period, to identify activities planned for the next reporting period, to identify issues that may affect performance and expenditures, to verify match funds are being proportionally spent concurrently or in advance of CEC funds or are being spent in accordance with an approved Match Funding Spending Plan, to form the basis for determining whether invoices are consistent with work performed, and to answer any other questions from the CAM. Monthly calls might not be held on those months when a Quarterly Progress Report is submitted or the CAM determines that a monthly call is unnecessary.
The CAM shall:
• Schedule monthly calls
• Provide questions to the Recipient prior to the monthly call • Provide call summary notes to Recipient of items discussed during call The Recipient shall:
• Review the questions provided by CAM prior to the monthly call • Provide verbal answers to the CAM during the call
Product:
• Email to CAM concurring with call summary notes
Task 1.5 Quarterly Progress Reports
The goal of this task is to periodically verify that satisfactory and continued progress is made towards achieving the objectives of this Agreement on time and within budget.
The objectives of this task are to summarize activities performed during the reporting period, to identify activities planned for the next reporting period, to identify issues that may affect performance and expenditures, and to form the basis for determining whether invoices are consistent with work performed.
The Recipient shall:
• Prepare a Quarterly Progress Report which summarizes all Agreement activities conducted by the Recipient for the reporting period, including an assessment of the ability to complete the Agreement within the current budget and any anticipated cost overruns. Progress reports are due to the CAM the 10th day of each January, April, July, and October. The Quarterly Progress Report template can be found on the ECAMS Resources webpage available at https://www.energy.ca.gov/media/4691. 30 Redwood Coast Energy Authority
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Product:
• Quarterly Progress Reports
Task 1.6 Final Report
The goal of the Final Report is to assess the project’s success in achieving the Agreement’s goals and objectives, advancing science and technology, and providing energy-related and other benefits to California.
The objectives of the Final Report are to clearly and completely describe the project’s purpose, approach, activities performed, results, and advancements in science and technology; to present a public assessment of the success of the project as measured by the degree to which goals and objectives were achieved; to make insightful observations based on results obtained; to draw conclusions; and to make recommendations for further projects and improvements to the FTD project management processes.
The Final Report shall be a public document. If the Recipient has obtained confidential status from the CEC and will be preparing a confidential version of the Final Report as well, the Recipient shall perform the following activities for both the public and confidential versions of the Final Report.
The Recipient shall:
• Prepare an Outline of the Final Report, if requested by the CAM. • Prepare a Final Report following the latest version of the Final Report guidelines which will be provided by the CAM. The CAM shall provide written comments on the Draft Final Report within fifteen (15) working days of receipt. The Final Report must be completed at least 60 days before the end of the Agreement Term.
• Submit one bound copy of the Final Report with the final invoice.
Products:
• Outline of the Final Report, if requested
• Draft Final Report
• Final Report
Task 1.7 Identify and Obtain Matching Funds
The goal of this task is to ensure that the match funds planned for this Agreement are obtained for and applied to this Agreement during the term of this Agreement.
The costs to obtain and document match fund commitments are not reimbursable through this Agreement. Although the CEC budget for this task will be zero dollars, the Recipient may utilize match funds for this task. Match funds shall be spent concurrently or in advance of CEC funds for each task during the term of this Agreement. Match funds must be identified in writing and the associated commitments obtained before the Recipient can incur any costs for which the Recipient will request reimbursement. 31 Redwood Coast Energy Authority
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The Recipient shall:
• Prepare a letter documenting the match funding committed to this Agreement and submit it to the CAM at least 2 working days prior to the kick-off meeting. If no match funds were part of the proposal that led to the CEC awarding this Agreement and none have been identified at the time this Agreement starts, then state such in the letter. If match funds were a part of the proposal that led to the CEC awarding this Agreement, then provide in the letter a list of the match funds that identifies the:
o Amount of each cash match fund, its source, including a contact name, address and telephone number and the
task(s) to which the match funds will be applied.
o Amount of each in-kind contribution, a description,
documented market or book value, and its source, including a contact name, address and telephone number and the
task(s) to which the match funds will be applied. If the in-kind contribution is equipment or other tangible or real property, the Recipient shall identify its owner and provide a contact name, address and telephone number, and the address
where the property is located.
• Provide a copy of the letter of commitment from an authorized representative of each source of cash match funding or in-kind contributions that these funds or contributions have been secured. For match funds provided by a grant a copy of the executed grant shall be submitted in place of a letter of commitment.
• Discuss match funds and the implications to the Agreement if they are reduced or not obtained as committed, at the kick-off meeting. If applicable, match funds will be included as a line item in the progress reports and will be a topic at CPR meetings.
• Provide the appropriate information to the CAM if during the course of the Agreement additional match funds are received.
• Notify the CAM within 10 days if during the course of the Agreement existing match funds are reduced. Reduction in match funds must be approved through a formal amendment to the Agreement and may trigger an additional CPR meeting.
Products:
• A letter regarding match funds or stating that no match funds are provided • Copy(ies) of each match fund commitment letter(s) (if applicable) • Letter(s) for new match funds (if applicable)
• Letter that match funds were reduced (if applicable)
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Task 1.8 Identify and Obtain Required Permits
The goal of this task is to obtain all permits required for work completed under this Agreement in advance of the date they are needed to keep the Agreement schedule on track.
Permit costs and the expenses associated with obtaining permits are not reimbursable under this Agreement. Although the CEC budget for this task will be zero dollars, the Recipient may budget match funds for any expected expenditures associated with obtaining permits. Permits must be identified in writing and obtained before the Recipient can make any expenditure for which a permit is required.
The Recipient shall:
• Prepare a letter documenting the permits required to conduct this Agreement and submit it to the CAM at least 2 working days prior to the kick-off meeting. If there are no permits required at the start of this Agreement, then state such in the letter. If it is known at the beginning of the Agreement that permits will be required during the course of the Agreement, provide in the letter:
o A list of the permits that identifies the:
Type of permit
Name, address and telephone number of the permitting
jurisdictions or lead agencies
o The schedule the Recipient will follow in applying for and obtaining these permits.
• Discuss the list of permits and the schedule for obtaining them at the kick-off meeting and develop a timetable for submitting the updated list, schedule, and the copies of the permits. The implications to the Agreement if the permits are not obtained in a timely fashion or are denied will also be discussed. If applicable, permits will be included as a line item in the Progress Reports and will be a topic at CPR meetings. • If during the course of the Agreement additional permits become necessary, provide the appropriate information on each permit and an updated schedule to the CAM.
• As permits are obtained, send a copy of each approved permit to the CAM.
• If during the course of the Agreement permits are not obtained on time or are denied, notify the CAM within 5 working days. Either of these events may trigger an additional CPR.
Products:
• Letter documenting the permits or stating that no permits are required • A copy of each approved permit (if applicable)
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• Updated list of permits as they change during the term of the Agreement (if applicable)
• Updated schedule for acquiring permits as changes occur during the term of the Agreement (if applicable)
• A copy of each final approved permit (if applicable)
Task 1.9 Obtain and Execute Subawards
The goal of this task is to ensure quality products and to procure subrecipients required to carry out the tasks under this Agreement consistent with the Agreement Terms and Conditions and the Recipient’s own procurement policies and procedures.
The Recipient shall:
• Manage and coordinate subrecipient activities.
• If requested by the CAM, submit a draft of each subaward required to conduct the work under this Agreement to the CAM for review. • If requested by the CAM, submit a final copy of the executed subaward. • If Recipient intends to add new subrecipients or change subrecipients, then the Recipient shall notify the CAM.
Products:
• Letter describing the subawards needed, or stating that no subawards are required
• Draft subcontracts (if requested)
• Final subcontracts (if requested)
TECHNICAL TASKS
TASK 2 CHARGING NETWORK FINAL PLANNING AND DESIGN
Task 2.1 Finalize Agreements Between Site Hosts & RCEA as the Network Administrator
The goal of this task is to finalize the agreements between the owners of the sites included in the project and RCEA, and obtained executed contracts for each site. The site owners have agreed to act as the site hosts and provide electricity for the EVSE.
The RCEA has agreed to act as the Network Administrator and own, operate, maintain, and collect data from the EVSE.
The Recipient shall:
• Draft a contract defining the relationship between the site hosts and RCEA • Meet with site hosts to review the contract term
• Revise the contract as needed for specific sites
• Obtain signed contracts from all participating site hosts 34 Redwood Coast Energy Authority
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Products:
• Copies of final, executed contracts for each site
Task 2.2 Final Selection of EVSE
The goal of this task is to select the manufacturer and model of the EVSE to be installed under the project. The costs estimates for each site are based upon the ChargePoint Model CT4000.
The Recipient shall:
• Make a final selection and procure Level 2 EVSE for the project. The EVSE will be provided to the contractor, who will be selected by the public bid process, for installation as part of the construction project. RCEA will oversee installation by the contractor and be responsible for installation activities.
Products:
• Summary memo explaining final EVSE selection, including number of stations and charging ports installed at each site, network capability, and payment options
• Invoice for purchase of Level 2 EVSE for the project
Task 2.3 Final Civil and Electrical Engineering
The goal of this task is to complete the civil and electrical engineering design for each of the sites finalized in Task 2.1. This includes verifying the site layout details with the site host, finalizing the site plan, identifying details including signage, and specifications under the seal of a licensed professional civil engineer, load calculations for the service panel or transformer that will supply the EVSE, and final plans and specifications.
The Recipient shall:
• Meet with site hosts to create preliminary site plan and verify that the layout meets the needs of the site host
• Finalize the civil engineering drawings for all sites • Update the Engineer’s Opinion of Probable Costs for each site to track potential changes against the granted budget for each site • Prepare civil engineering specifications
• Prepare civil engineering details
• Conduct a load calculation for each service panel proposed to supply EVSE under the project
• Coordinate with PG&E’s engineering department regarding requirements for new transformer taps where needed
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• Provide construction-ready design drawings and specifications stamped by a registered electrical engineer for each of the project locations • Provide additional drawings, information, and documentation as needed for Pacific Gas & Electric and local permitting officials Products:
• 90% civil and electrical engineering plans, specifications, and cost estimates for each installation
• Final, stamped civil and electrical engineering plans, specifications, and cost estimates for each site that takes into account the comments provided on the 90% submittal
• Final construction specifications
Task 2.4 Construction Project Bidding
The goal of this task is to solicit bids for the construction of the ten EVSE installations as one public works construction project. Competitive bids from licensed contractors will be solicited following public contract code requirements as required by the procurement policies of the Redwood Coast Energy Authority. Note that several sites are hospitals with additional life-safety compliance requirements, and for cost-effectiveness these sites may be treated with an alternative bid process where hospitals have qualified electricians on staff or under contract.
The Recipient shall:
• Prepare a set of General Conditions which will act as the governing contract between the Redwood Coast Energy Authority and the lowest responsive, responsible bidder of the construction project • Issue the General Conditions, stamped final engineering plans, and stamped construction specifications for bidding following public contract code requirements
• Respond to contractor’s questions on the project during the bid process • Issue addenda as required to amend the construction contract documents as appropriate during bidding
• Host a public bid opening where sealed bids will be opened and read aloud, bid forms will be reviewed for completeness and the lowest bidder will be announced
• Check the license status of the apparent lowest responsive, responsible bidder
• Recommend that RCEA issue the notice of award to the lowest responsive, responsible bidder
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• Check performance and payment bonds and certificates of insurance provided by the contractor for conformance with the contract documents • Recommend that the RCEA issue the Notice to Proceed to the contractor Products:
• Bid Package including General Conditions, final stamped engineering plans and construction specifications, and addenda if applicable • Summary of bid results
• Copies of Notice of Award and Notice to Proceed
TASK 3 CHARGING NETWORK CONSTRUCTION & START-UP OPERATIONS Task 3.1 Construction Contract Administration
The goal of this task is to administer the construction project to ensure that the project proceeds to a successful conclusion following the requirements of the construction contract documents, RCEA will administer the construction contract from the Notice to Proceed through the Notice of Completion.
The Recipient shall:
• Review and respond to submittals from the contractor for items of work such as: conduit, wire, concrete mix design, EVSE anchor bolts, light poles, light fixtures, signage, sign posts, wheel stops, electrical pull boxes, meters, circuit breakers, junction boxes, and service pedestals where transformer taps are required, pavement letters and striping, etc.
Submittals will be reviewed and responded to in a timely manner so as to avoid delays and ensure that the products provided meet the requirements of the contract documents.
• Manage construction contract costs including:
• Review progress payment requests from the contractor for conformance with work completed and make a recommendation to the RCEA for payment of an appropriate amount for the work completed, minus a 10% retainage, which will be released at the end of the project.
• Negotiate any requests for contract change orders submitted by the contractor in a fair and timely manner.
• Recommend that the RCEA submit a Notice of Completion for the project after all the work has been confirmed to be completed in accordance with the contract documents. The Notice of Completion package will include a form for each site with the site owner’s signature indicating that the project is complete.
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• Recommend final payment of all retained money upon the receipt by the RCEA of a release of liability signed by the contractor after the Notice of Completion has been filed by the County Recorder’s office. • Submit an AB 841 Certification that certifies the project has complied with all AB 841 (2020) requirements specified in the Agreement Terms and Conditions or describes why the AB 841 requirements do not apply to the project. The certification shall be signed by Recipient’s authorized representative. • Submit EVITP Certification Numbers of each Electric Vehicle Infrastructure Training Program certified electrician that installed electric vehicle charging infrastructure or equipment. EVITP Certification Numbers are not required to be submitted if AB 841 requirements do not apply to the project.
Products:
• Copies of all submittals and responses
• Copies of any contract change orders if applicable
• Copies of progress pay requests from the contractor
• Copy of the Notice of Completion Package
• Copy of the signed Waiver and Release of Liability Form • AB841 and EVITP certifications
Task 3.2 Construction Observation
The goal of this task is to provide quality assurance and control during the construction of the EVSE installations through the presence of a construction observer, who will report directly to RCEA. RCEA will be responsible for all project construction activities .
The Recipient shall:
• Verify by visual observation that the installations are built according to the final design plans and specifications
• Check that products brought onsite by the contractor for installation match those in the submittals that have been reviewed
• Document the construction by completing a construction observation log daily and through photographic documentation
• Facilitate the timely resolution of complications that arise during construction such as unforeseen site conditions, utility conflicts, errors and/or omissions in the contract documents, etc.
• Verify contractor conformance with permit conditions
Products:
• Copy of construction log and photographic documentation 38 Redwood Coast Energy Authority
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[CPR WILL BE HELD IN THIS TASK. See Task 1.2 for details] Task 3.3 Upload New EVSE Installations To Internet Sites, Navigation Systems, and Apps
The goal of this task is to confirm that each of the new EVSE appears and is accurately represented on EVSE locator websites, smartphone applications, and vehicle navigation systems. This task will occur upon completion of each installation and periodically thereafter to ensure that EVSEs are easy to find and clearly described in the cloud.
The Recipient shall:
• Upon completion of each new EVSE installation, compile geographic location, brief description, charging capacity, fee schedule, and photos for each site and publish them to websites such as the US Department of Energy Alternative Fuels Data Center Station Locator, ChargePoint, and PlugShare, among others
• Update links to station locator websites on the RCEA website page that describes the North Coast Plug-In Electric Vehicle Charging Network Project Phase 2
• Periodically check the websites and apps to monitor comments from users as a way of improving the Network
• Update selected websites with changes to the Network such as pricing and usage policy changes, maintenance and upgrades of EVSE, addition of new EVSE at the same location due to high demand, etc • Organize a launch event to alert the community about the availability of the stations and educate residents and business owners on the benefits of electric vehicles and EV charging stations
Products:
• Printouts of web pages showing EVSE details for each of the sites in the Network that are funded by the grant
• Printout of the RCEA webpage that describes the North Coast Plug-In Electric Vehicle Charging Network Project Phase 2
• Summary of user comments that provide feedback for improving the Network • Summary of launch event media, such as a social media postings, newspaper articles, and site photographs and statements.
TASK 4 DATA COLLECTION AND ANALYSIS
The goal of this task is to collect operational data from the project, to analyze that data for economic and environmental impacts, and to include the data and analysis in regular progress reports and the Final Report.
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The Recipient shall:
• Develop data collection plan for deployed charging equipment. • Troubleshoot any issues identified.
• Collect and provide the following data:
o Number, type, date, and location of chargers installed. o Nameplate capacity of the installed equipment, in kW for chargers. o Number and type of outlets per charger.
o Location type, such as street, parking lot, hotel, restaurant, or multi-unit housing. o Total cost per charger, the subsidy from the CEC per charger, federal subsidy per charger, utility subsidy per charger, and privately funded share per charger.
• Collect and provide 12 months of throughput, usage, and operations data from the project including, but not limited to:
o Number of charging sessions
o Average charger downtime
o Peak power delivered (kW)
o Duration of active charging, hourly
o Duration of charging session, hourly (e.g., vehicle parked but not actively charging)
o Average session duration
o Energy delivered (kWh)
o Average kWh dispensed
o Types of vehicles using the charging equipment
o Applicable price for charging, including but not limited to: electric utility tariff, electric vehicle service provider (EVSP) service contract, or public charger price.
o Payment method for public charging
o Energy delivered back to grid or facility if a bidirectional charging use case (kWh)
o Normal operating hours, uptime, downtime, and explanations of variations
o Gallons of gasoline and/or diesel fuel displaced (with associated mileage information)
o Expected air emissions reduction, for example:
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Non-methane hydrocarbons
Oxides of nitrogen
Particulate Matter
Formaldehyde
• Identify any current and planned use of renewable energy. • Describe any energy efficiency measures used that may exceed Title 24 standards in Part 6 of the California Code of Regulations. • Provide data on potential job creation, economic development, and increased state revenue as a result of the project and any expected future expansion.
• Provide a quantified estimate of the project’s carbon intensity values for life-cycle greenhouse gas emissions.
• Compare any project performance and expectations provided in the proposal to CEC with actual project performance and accomplishments. • Submit the data described above electronically in a quarterly progress report throughout the duration of the agreement.
• Collect data, information, and analysis described above and include in the Final Report.
Products:
• Data on charger installations and charging events will be submitted electronically in Quarterly Progress Reports.
• Data collection information and analysis will be included in the Final Report.
TASK 5 PROJECT FACT SHEET
The goal of this task is to develop an initial and final project fact sheet that describes the CEC-funded project and the benefits resulting from the project for the public and key decision makers.
The Recipient shall:
• Prepare an Initial Project Fact Sheet at start of the project that describes the project and the expected benefits. Use the format provided by the CAM.
• Prepare a Final Project Fact Sheet at the project’s conclusion that describes the project, the actual benefits resulting from the project, and lessons learned from implementing the project. Use the format provided by the CAM.
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• Provide at least (6) six High Quality Digital Photographs (minimum resolution of 1300x500 pixels in landscape ratio) of pre and post technology installation at the project sites or related project photographs.
Products:
• Initial Project Fact Sheet
• Final Project Fact Sheet
• High Quality Digital Photographs
TASK 6 OPERATIONS AND MAINTENANCE
The goal of this task is to ensure that the chargers installed in the project are operational at least 97 percent of a charging site’s standard hours of operation for five years after commissioning.
Task 6.1 Operations
The Recipient shall:
• Operate the installed charging stations during the term of this agreement. • Ensure that the chargers installed in the project are operational at least 97 percent of a charging site’s standard hours of operation for five years after commissioning. Without limitation to other rights and remedies which the CEC may have, including but not limited to survival provisions specified in the Terms and Conditions of this agreement, this requirement to ensure operationality for five years after commissioning shall survive the completion or termination date of this agreement. In addition to other requirements in the Terms and Conditions of this agreement, all CEC-reimbursable expenditures must be incurred within the agreement term.
Task 6.2 Maintenance
The Recipient shall:
• Perform regular preventive maintenance, including visual inspection, performance testing, functional validation, and reporting. • Monitor network performance.
• Dispatch maintenance technicians in a timely manner and address malfunctions and repairs within 48 hours of initial notice.
• Provide charging station users with 24/7 call center service that will assist users with any technical issues encountered at the stations.
• Prepare a Stations Operations Report for each project site sent quarterly to the CAM after station commissioning through the term of this agreement. The report will include a summary of uptime measures, calculation of uptime, and number of dispatch events needed during the quarter.
Product:
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• Stations Operations Reports delivered with the Quarterly Progress Reports described in Task 1.5
Task 6.3 Recordkeeping and Reporting
The Recipient shall:
• Keep and maintain a record of the standard hours of operation for each site, including any changes over the operational period.
• Keep and maintain detailed records of maintenance and repairs. Records shall include:
o Whether the maintenance was scheduled preventive maintenance or response to an identified issue
o Date and time the need for corrective maintenance was reported, if applicable o Date and time maintenance began
o Date and time maintenance was completed
o Narrative describing nature of maintenance required
o Any component failures / replacements
• Keep and maintain a record of the operative status of each connector from the time the equipment is commissioned until the end of the operational period defined by this agreement.
o The record shall include any time the Recipient knows or is notified that a connector is incapable of delivering a charge, for example by observation, by receipt of a service call, by notice of power outage or telecommunications outage, or other means.
o For any networked chargers, Recipient shall record the time and the operative status of each connector every 15 minutes.
For example, a central system using OCPP 1.6 could send TriggerMessage.req, ‘requestedMessage’ = ‘StatusNotification’ and record both the TriggerMessage.conf and StatusNotification.req sent by the charge point in response.
o Excluded downtime shall be recorded, including any supporting documentation from an independent party, e.g., notice from an electric utility of a power outage or police report of vandalism. The record shall include an explanation of the cause of the downtime, why it should be considered excluded downtime, and the efforts made to minimize the downtime.
• Make these records available, in a standard electronic format of the CEC’s choosing, to the CEC within 10 business days of a written request by the CEC. 43 Redwood Coast Energy Authority
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• Without limitation to other rights and remedies which the CEC may have, including but not limited to survival provisions specified in the Terms and Conditions of this agreement, the requirements for recordkeeping and reporting under this Task shall remain in effect for five years after commissioning and shall survive the completion or termination date of this agreement. In addition to other requirements in the Terms and Conditions of this agreement, all CEC-reimbursable expenditures must be incurred within the agreement term. • The requirements for recordkeeping and reporting under this Task are in addition to requirements specified in this Agreement’s Terms and Conditions, section
18.b, Retention of Records, and any other applicable Terms and Conditions.
Products:
• Record of standard hours of operation
• Record of the operative status of each connector
• Records of maintenance and repairs
Task 6.4 Definitions
a. Central System: The central system that communicates with one or more chargers, for example, to authorize users, monitor charger status, and/or collect, transmit, record, and manage other information.
b. Connector: A connector is what is plugged into a vehicle to charge it. c. Charging Site: A physical location with one or more chargers. d. Charger: A device that safely supplies electrical power to an electric vehicle through connectors. Where a device has multiple connectors or can serve multiple parking spaces, the number of chargers is equal to the number of vehicles that can be simultaneously charged. Charger is synonymous with port. e. Downtime: Any period of time within the standard hours of operation in which a charger is not operational.
For networked chargers, a period in which the charge point’s response to the central system’s request for notification of operative status indicates that the connector or charge point is in an inoperative state is downtime.
• For example, in OCPP 1.6 intervals when StatusNotification.req protocol data unit Status Field = ‘Unavailable’ or ‘Faulted’ OR errorCode Field = ‘ConnectorLockFailure’, ‘GroundFailure’, ‘HighTemperature’, ‘InternalError’, ‘OverCurrentFailure’, ‘OverVoltage’, ‘PowerMeterFailure’, ‘PowerSwitchFailure’, ‘ReaderFailure’, ‘ResetFailure’, or ‘UnderVoltage’ are “downtime.” f. Excluded downtime: A period of downtime, within the standard hours of operation, caused by any of the following:
• Electric Grid Power Loss: Power supplied by the electric utility for a site is not supplied at levels required to for minimum function of chargers / station. This may include, but is not limited to, service outages due to utility equipment malfunction or public safety power shut-offs.
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• Accident, Vandalism or Theft: Physical damage to the charger for events such as vehicle collision with a charger, theft of charging cables, damage to connectors from mishandling, and damage to screens. Excluded downtime is limited to a maximum of 5 days for each event.
• Telecommunication Network Outages: Loss of communication between a charger and a central system due to cellular or internet service provider system outages that are beyond the control of the Recipient.
• Planned Outage for Maintenance or Upgrade: Any planned maintenance indicated in the funding Recipient’s Operations and Maintenance Plan, submitted with application for funding, or an updated Plan approved by the CAM in advance of the planned outage.
• Extraordinary Events: Unforeseeable events that would have been impossible to plan for using commercially reasonable methods.
g. Operational: A charging port is considered operational when its hardware, and software are both online and available for use, or in use, and the charging port successfully dispenses electricity as expected.
h. Uptime: Uptime is calculated as:
Uptime = Total Standard Hours of Operation – Downtime + Excluded Downtime Total Standard Hours of Operation ∗ 100%
45 Template Version 08/23/2021
Agreement Number
Name of Organization
Cost Category CEC Share Match Share Total
Direct Labor $ 40,283 $ 40,283 $ 80,566
Fringe Benefits $ 17,924 $ 17,924 $ 35,848
Total Labor $ 58,207 $ 58,207 $ 116,414
Travel $ 1,710 $ - $ 1,710
Equipment $ 243,200 $ - $ 243,200
Materials/Miscellaneous $ 89,600 $ 1,000 $ 90,600
Subrecipients/Vendors $ 284,000 $ 92,510 $ 376,510
Total Other Direct Costs $ 618,510 $ 93,510 $ 712,020
Indirect Costs $ 23,283 $ 23,283 $ 46,566
Profit
(not allowed for grant recipients) $ - $ - $ -
Total Indirect and Profit $ 23,283 $ 23,283 $ 46,566
Grand Totals $ 700,000 $ 175,000 $ 875,000
Total CEC Reimbursable Funds Spent in California
or Paid to California-Based Entities
(if applicable)
$ -
Percentage of CEC Reimbursable Funds Spent in
California or Paid to California-Based Entities
Recipient
Select your company's California Business Certifications GFO-21-604
PROPOSAL BUDGET
Redwood Coast Energy Authority
Category Budget
Attachment 05 Page 1 of 1 GFO-21-603
46 Public Comment
September 22, 2022
Board of Directors Meeting
6.1 - Rural Electric Vehicle Charging CEC Grant
STAFF REPORT
Agenda Item # 7.1
AGENDA DATE: September 22, 2022
TO: Board of Directors
PREPARED BY: Jocelyn Gwynn, Power Resources Manager
SUBJECT: Renewable America North Bank Road Projects Update
BACKGROUND
At the January 2022 meeting, the Board approved a shortlist of three projects under RCEA’s 2021 Mid-Term Reliability solicitation. Two of those projects are for new local solar plus storage facilities being developed by Renewable America (RNA), one on Foster Road in Arcata and the other off North Bank Road near McKinleyville. The power purchase agreement (PPA) for the Foster Clean Power A project is being brought to the Board for approval at this meeting in a separate agenda item. The North Bank Clean Power project has changed in scope and timeline from the original offer which has prompted staff to pause the negotiation and seek Board authorization to continue considering it for procurement.
SUMMARY
Since shortlisting North Bank Clean Power, Renewable America has informed RCEA staff that the project has changed names to North River Clean Power and has moved to an adjacent parcel northwest of the original site that is owned by the same landowner. Due to the site change, RNA is able to scale up the solar capacity from 1 MW to 5 MW, plus an equivalent increase in storage capacity. In addition to this change, the project would now become operational in late 2025, which is past the relevant deadline for RCEA’s CPUC Mid-Term Reliability (MTR) procurement obligation.
At the former North Bank project site, RNA is now proposing to build a 1 MW solar facility without energy storage called Mad River Solar, which they have offered to RCEA’s Feed-In Tariff (FIT) program. However, the FIT program only has 0.5 MW of capacity left, so RCEA is only able to procure half the project size via this mechanism. RNA has reported that the viability of interconnecting the Mad River Solar project is contingent on the construction of the larger North River Clean Power project, because the necessary PG&E distribution upgrades would be cost prohibitive for the smaller project alone. Should the Board approve continued negotiations for procurement of North River Clean Power and a final PPA, staff would bring the Mad River Solar FIT PPA to the Board for consideration at a subsequent meeting.
Although the North River project no longer meets MTR compliance need, staff are recommending the Board authorize continued consideration of the project for local solar development purposes.
The CCE Program Launch Period Strategy and Targets1 adopted by the Board in 2016 includes a 1 https://redwoodenergy.org/wp-content/uploads/2018/12/RCEA-Community-Energy-Program-Guidelines_Update-5.21.18.pdf 47
goal to develop 15 MW of local utility-scale solar in the first five years of the program. With the Redwood Coast Airport Microgrid, the Hatchery Road and North Coast Highway FIT projects, and the Foster Clean Power A project (if approved by the Board), RCEA will have procured 11 MW.
The addition of these two RNA projects would meet the Board’s solar development goals once the projects are all operational.
ALIGNMENT WITH RCEA’S STRATEGIC PLAN
By continuing to build RCEA’s portfolio of long-term, local renewable and storage resources, this project contributes to many Strategic Plan goals:
• 4.1.1 Maximize the Use of Local Renewable Energy to the Extent Technically and Economically Feasible and Prudent.
• 4.1.2 Minimize Greenhouse Gas Emissions Associated with RCEA’s CCE Program. • 4.1.4 Maximize Renewable Energy Content of RCEA’s CCE Program. • 4.1.5 Ensure Diversity in Local Sources
• 4.1.7.2 Develop Distributed Generation.
• 4.1.8.1 Support Utility Scale Solar Energy Development. • 4.1.8.2 Procure Local Solar Energy.
EQUITY IMPACTS
Renewable America is not listed in the CPUC’s Supplier Diversity Clearinghouse as a diverse business enterprise. They are working with GRID Alternatives on workforce development opportunities through this and their other projects, including potential community benefit or project labor agreements.
FINANCIAL IMPACT
There are no financial impacts of the proposed action other than staff and counsel time to negotiate the agreement. In the case that the Board eventually approves the North River Clean Power PPA, initial analysis by The Energy Authority shows that the expected value of the energy, renewable energy certificates (RECs) and resource adequacy (RA) from the project is at parity with the contract cost over the term of the agreement. These costs are already accounted for in RCEA’s financial model and would be incorporated into the budget starting in fiscal year 2025- 2026. This project would also bring value to RCEA’s long-term portfolio as a hedge against price volatility risk for energy, RECs, and RA.
STAFF RECOMMENDATION
Authorize staff to continue negotiations with Renewable America of a long-term power purchase agreement for the 5 MW North River Clean Power solar plus storage project.
ATTACHMENTS
None
48 Former
site of 1
MW
project:
New site
of 5 MW
project:
Former site
being used
for solar-only FIT
project:
STAFF REPORT
Agenda Item # 8.1
AGENDA DATE: September 22, 2022
TO: Board of Directors
PREPARED BY: Richard Engel, Power Resources Director
Jocelyn Gwynn, Senior Power Resources Manager
SUBJECT: Integrated Resource Plan Portfolio Review
BACKGROUND
Load serving entities (LSEs) including RCEA are required to submit an Integrated Resource Plan (IRP) to the California Public Utilities Commission (CPUC) every two years. Integrated resource planning is a standard long-term planning exercise conducted by utilities to analyze supply and demand resources needed to meet customer load at affordable rates. In California, IRPs also address non-energy requirements that the LSE must meet, such as system reliability, dependence on unspecified system power, renewable resource integration, greenhouse gas (GHG) emissions targets, and consideration of impacts that power portfolios may have on disadvantaged communities.
RCEA’s last IRP was submitted September 1, 2020, and this cycle’s plans are due November 1.
The CPUC is requiring LSEs to submit two portfolios, one of which must conform to a GHG-emissions benchmark for the electric sector of 38 MMT in 2030 and 30 MMT in 2035, and another that conforms to a benchmark of 30 MMT in 2030 and 25 MMT in 2035. However, if an LSE’s selected portfolio, known as the preferred conforming portfolio, results in GHG emissions below the lower of the two GHG planning scenarios, then the LSE may submit only one portfolio. Based on RCEA’s plans for transitioning to clean and renewable power sources, staff expect to be able to utilize this option.
In addition to meeting RCEA’s allotted GHG emissions benchmark, the portfolio must conform to the CPUC’s guidelines including an assigned load forecast and consistency with the state’s Preferred System Plan (PSP). After submission of the IRPs, the CPUC aggregates all the plans into a system-level plan that will be utilized in state planning processes including the California Independent System Operator’s (CAISO) Transmission Planning Process.
SUMMARY
The attached table shows existing and candidate resources that RCEA is planning to include in its IRP portfolio. The final energy volumes by resource type are subject to change according to the portfolio analysis that is currently underway, and any Board feedback. The following assumptions are embedded in this proposed portfolio:
49
• All active and in-progress contracts included
• 40 MW of offshore wind procured and operational by 2030 • 18 MW biomass contract renewed past 2031
• 15 MW new geothermal procured and operational by 2030 • 20 MW solar + storage procured for Mid-Term Reliability compliance and operational by 2025
• 8 MW of new local small hydropower operational by 2030 • 10 MW new local battery storage operational by 2026
• Second phase of Feed-In Tariff Program rolled out 2023-2024 resulting in additional 6 MW solar + 6 MW storage operational 2025-2027
• Development of two additional community scale microgrids by 2026-2030 • PG&E Renewable Portfolio Standard & Carbon-Free Allocations contracted through 2035 • Balance of portfolio through 2029 met with short-term carbon-free energy In addition to the proposed portfolio, staff are analyzing the following portfolio configurations:
a) Maximize offshore wind procurement without renewing the biomass contract b) Maximize new Northern CA geothermal procurement without renewing the biomass contract and without offshore wind procurement
c) Short-term existing solar and wind procurement in lieu of offshore wind, new geothermal, or additional biomass (this is for comparison purposes only) Once staff have incorporated any feedback provided by the Board at this month’s meeting, the Board will be asked to approve the full IRP filing at the October meeting in advance of submission to the CPUC on November 1.
ALIGNMENT WITH RCEA’S STRATEGIC PLAN
Candidate resources for the IRP portfolio were chosen according to RCEA’s Strategic Plan, in particular the local solar, battery storage, offshore wind and small hydropower projects.
EQUITY IMPACTS
Not applicable.
FINANCIAL IMPACT
Apart from staff and consultant time required to prepare the filings, there is no direct cost or other financial impact associated with the filings themselves. The IRP filing carries no binding commitments for procurement and is revised every two years. However, development of the IRP in particular is a risk management activity that mitigates financial risk exposure for RCEA by ensuring holistic, high-level decision-making regarding our community choice energy program’s power portfolio, while ensuring conformance with regulatory mandates from the State.
STAFF RECOMMENDATION
Provide feedback to staff on the proposed Integrated Resource Plan portfolio.
ATTACHMENTS
Proposed IRP Portfolio Table
50 Resource Type
Energy Production (GWh)
Existing Resources New Resources
2024 2026 2030 2035
Hydro (Large) 305 300 35 35 PG&E Voluntary Allocation,
Short-Term Contracts* None
Hydro (Small) 10 10 35 25 Cove Hydro, Short-Term
Contracts* New Local Small Hydro Project*
Biogas <1 <1 <1 <1 PG&E Voluntary Allocation None
Biomass 100 100 100 100 Humboldt Redwood,
PG&E Voluntary Allocation None
Geothermal 5 35 115 115 None CC Power Geothermal Projects, Northern California Geothermal Project*
Wind (Onshore) 20 20 15 5 PG&E Voluntary Allocation,
Short-Term Contracts* None
Wind (Offshore) 0 0 190 190 None Redwood Offshore Wind* Utility Scale Solar 250 250 245 240 PG&E Voluntary Allocation, Short-Term Contracts Sandrini Sol 1, FIT Phase I Projects Customer Solar1 100 120 150 185 Existing Behind-the-Meter Solar Future Behind-the-Meter Solar
Hybrid Solar + Storage 10 85 95 95 Redwood Coast Airport Microgrid
Foster Clean Power A, MTR Zero Emitting
Resource*, FIT Phase II Projects*, Local
Hybrid & Resiliency Projects*
Battery Storage (MW) 20 40 40 20 Tierra Buena Energy
Storage
Fairhaven, CC Power Long Duration Storage
Projects, Local Energy Storage Project*
Demand Response (MW) 5 5 5 5 Leapfrog DR Aggregation None Total Supply2 700 800 830 805
Forecasted Load3 732 735 740 744
GHG Emissions (MMT CO2) 0.053 0.035
RCEA GHG Emissions Benchmarks (MMT
CO2) 0.074 0.057
* Indicates planned resources that are not yet contracted 1 RCEA would not contract for behind-the-retail-meter customer solar, but this forecast is accounted for in RCEA’s assigned load forecast 2 Represents supply before combined heat and power assignment and curtailments during high generation hours; does not include customer solar, battery storage or demand response
3 Includes assigned forecasts for customer solar, energy efficiency, electric vehicle load and building electrification 51 Integrated Resource Plan
Portfolio Review
Presentation to RCEA Board of Directors
September 22, 2022
Integrated Resource Planning Overview
• California Public Utilities Commission (CPUC) requires submission of an integrated resource plan (IRP) every two years
• IRP due November 1 will be RCEA’s third since 2018, when CCAs were first required to prepare them
• Staff will bring Board final IRP for approval at October meeting • Portfolio shown in IRP is not a binding commitment; RCEA has opportunity to update its preferred portfolio every two years
• Each load-serving entity needs to demonstrate that their portfolio meets state requirements for decarbonization, reliability, and cost-effectiveness • CPUC aggregates all the IRPs submitted for statewide planning purposes Portfolios for Analysis
Portfolio
Number
Name Description Biomass Offshore Wind Geothermal
1 Diverse
Portfolio
Biomass extended plus some
offshore wind, geothermal
18 MW through
2035
40 MW in 2030 15 MW in 2030
2 Maximum
Offshore Wind
Short-term RPS procurement
bridging gap to offshore
wind
None after 2031
HSC expiration
75 MW in 2030 None
3 Maximum
Geothermal
Ramping up geothermal
procurement as biomass
ends
None after 2031
HSC expiration
None 20 MW in 2030,
40 MW by 2035
4 Short-term
Solar and
Wind
Baseline scenario for
comparison
None after 2031
HSC expiration
None None
Proposed “Preferred Conforming Portfolio” for Integrated Resource Plan Preferred
Conforming
Portfolio
Assumptions
• All active and in-progress contracts included
• 40 MW of offshore wind procured and operational by
2030
• 18 MW biomass procured past 2031 (could come from
alternative, cleaner sources)
• 15 MW new geothermal procured and operational by
2030
• 20 MW solar + storage procured for Mid-Term Reliability compliance and operational by 2025
• 8 MW of new local small hydropower operational by
2030
• 10 MW new local battery storage operational by 2026
• Second phase of Feed-In Tariff Program rolled out 2023- 2024 resulting in additional 6 MW solar + 6 MW storage operational 2025-2027
• Development of two additional community scale
microgrids by 2026-2030
• PG&E Renewable Portfolio Standard & Carbon-Free
Allocations contracted through 2035
• Balance of portfolio through 2029 met with short-term carbon-free energy
Preferred
Conforming
Portfolio
Details
Questions for Board to Consider
1. Do you want to propose any adjustments to the staff recommended “Diverse Portfolio” for submission as RCEA’s Preferred Conforming Portfolio (blending new offshore wind and geothermal with continued procurement of biomass* beyond the 2031 HSC contract expiration)?
2. More specifically, do you support continued short-term large hydro procurement in the 2020s to save room in RCEA’s portfolio for offshore wind or other long-lead resources in 2030 and beyond?
*Biomass procurement after 2031 HSC contract expiration could potentially come from an alternative, cleaner source
STAFF REPORT
Agenda Item # 9.1
AGENDA DATE: September 22, 2022
TO: Board of Directors
FROM: Matthew Marshall, Executive Director
SUBJECT: Executive Director’s Report
SUMMARY
Executive Director Matthew Marshall will provide a brief update on:
• RCEA recent activities, and
• Other topics as needed.
RECOMMENDED ACTION
None. (Information only.)
ATTACHMENT
RCEA Monthly Report
56