Onyx Contract Amendment No. 1.pdf — Fairfield City Council, September 16, 2025 (part 1 of 2)

1 Revised September 2024
Amendment 1
To Power Purchase Agreement
Between
City of Fairfield
and
Onyx Development Group LLC

This Amendment No.1, made by and entered into as of the _____ day of ______________, 2025, by and between the CITY of FAIRFIELD, a municipal corporation (hereinafter “CITY”), AND Onyx Development Group LLC (hereinafter “ONYX”), for the purpose of reviewing and amending the Power Purchase Agreement (hereinafter “AGREEMENT”) dated August 26, 2024 between the parties. This Amendment does not take effect until signed by both parties.

The revisions to the AGREEMENT are limited to those specified below. All other provisions of the AGREEMENT remain in effect as set forth in Exhibit “A”.

The AGREEMENT is amended as follows:

1. Section 4, Subsection D, is amended as follows:

D. Provider’s Solar Facility Output Guarantee. Commencing with the second (2nd) Contract Year after the Commercial Operation Date of the System, and for each Contract Year thereafter during the Initial Term, the aggregate metered Solar Facility Output for the previous Contract Year (the “Measurement Period”) shall be at least ninety percent (90%) of the Annual Production Estimate for such Measurement Period for the Solar Facility as defined in Exhibit B (“Output Guarantee”); provided, the Annual Production Estimate is adjusted for actual weather conditions experienced at the Site, and the Output Gu arantee for any Measurement Period will be reduced by the estimated generation of the Solar Facility that would have been generated during such Measurement Period, but was not generated, due to one or more of the following causes: (i) Outage; (ii) the actions or omissions of the Distribution Utility or the request or direction of the Distribution Utility; (iii) a Force Majeure event; (iv) buildings or structures constructed after the Commercial Operation Date overshadowing or otherwise blocking access or sunlight to the Solar Facility on or at the Site; (v) a breach of this Agreement by City; (vi) any action or inaction by City that directly causes such reduction in generation (including but not limited to, pursuant to Sections 5.F, 11.C and 11.D below); or (v) a temporary outage pursuant to Section 11.E below. The Output Guarantee listed in Exhibit B is an estimate based upon the Project’s initial design and will be revised to reflect the as - built system once commissioned.

If the Solar Facility Output during any Measurement Period does not equal or exceed the Output Guarantee for such Measurement Period, Provider shall include in its next invoice to City (and in the final invoice for any credit owed for the final Contract Year) a credit for the Energy Shortfall Amount. Alternatively, City has the option to request that the Energy Shortfall Amount be paid by check independently of an invoice.

2 Revised September 2024

2. Section 4, Subsection E, is amended as follows:

E. Provider’s Battery Systems Guarantee . Commencing with the first (1st) Contract Year after the Commercial Operation Date of the System, and for each Contract Year until the end of the fifteenth (15th) Contract Year of the Initial Term (the “ Battery Guarantee Term”), the percentage of real time, measured and reported cumulatively by the supervisory control and data acquisition system, that one hundred percent (100%) of the nameplate power capacity of the Battery Systems (the “Battery Availability”) is available for the previous Contract Year (the Measurement Period) shall be equivalent to at least ninety percent (90%) of the total real time for such Measurement Period (8760 hours) (“ Battery Systems Guarantee ”); provided that, the Parties acknowledge and agree that the Battery Availability shall be reduced each Contract Year to account for the normal and expected degradation of the Battery System in accordance with manufacturer specifications; and provided further that the Battery Systems Guarantee for any Measurement Period will be reduced by the estimated real time that the Battery Systems would have been available during such Measurement Period, but was not available, due to one or more of the following causes: (i) an Outage; (ii) the actions or omissions of the Distribution Utility or the request or direction of the Distribution Utility; (iii) a Force Majeure event; (iv) a breach of this Agreement by City, (v) any action or inaction by City that directly causes such reduction in generation (including but not limited to, pursuant to Sections 5.F, 11.C and 11.D below); or (vi) a temporary outage pursuant to Section 11.E below. Real time shall be measured in increments of hours. Provider additionally guarantees that during the Battery Guarantee Term, the Battery Systems will be available to provide at least the number of cycles per Contract Year (“ Guaranteed Cycles”) indicated in Exhibit C when using the full Battery Systems kWh Rating. The Battery Systems shall be cycled in accordance with standard industry practices to maximize electricity cost savings to the City.

For the absence of doubt, the Parties acknowledge and agree that the Battery Guarantee Term shall terminate at the end of the fifteenth (15 th) Contract Year, and t hat beginning on the sixteenth (16th) Contract Year neither the Battery Systems Guarantee nor the Guaranteed Cycles shall apply. Provider shall either replace or augment the Battery Systems at the end of the fifteenth (15th) Contract Year to mitigate the degradation of the Battery Systems. At least thirty (30) days prior to the fifteenth (15 th) anniversary of the Commercial Operation Date, the Parties shall meet and endeavor in good faith to negotiate a Battery Systems Guarantee for the remaining ten (10) Contract Years of the Agreement to preserve the economic value of the Agreement to both Parties.

During the Battery Guarantee Term, i f the percentage of real time, measured and reported cumulatively by the supervisory control and data acquisition system, that one hundred percent (100%) of the nameplate power capacity of the Battery Systems is available during any Measurement Period does not equal or exceed the Battery Systems Guarantee for such Measurement Period (each of the Battery Availability and the Battery Systems Guarantee as shall be adjusted in accordance with this Section 4.E), Provider shall include in its next invoice to City a credit for the Battery Systems Energy Shortfall Amount. Alternatively, City has the option to request that the Battery Systems Energy Shortfall Amount be paid by check independently of an invoice.

3 Revised September 2024

3. Section 5, Subsection G, is amended as follows:

G. Operation and Maintenance of System . Provider shall be responsible for all operations, maintenance, and repair of the System, except to the extent that any maintenance or repair is made necessary by the negligent acts or omissions or willful misconduct of City. All maintenance, repairs an d operations, shall be conducted in the manner set forth in this Agreement, and Provider shall reasonably accommodate and cooperate with City to ensure the City’s activities, facility uses, and scheduling requirements are not unreasonably impeded.

Provider’s repair work responsibilities shall include, but are not limited to, any repair required as a result of damage caused by the Provider or its contractors, subcontractors or vendors, to the City’s facilities within a period of five (5) years following the date the damage was discovered or reasonably should have been discovered by the City. Provider is responsible for repairs and/or replacement of system components that are damaged from vandalism, theft or criminal activity. Provider shall provide grass cutt ing services at the Site at least once per calendar year between May 1 st and June 30 th following the Commercial Operation Date for purposes of weed abatement and vegetation control, provided that Provider shall not cut grass or otherwise provide vegetation control services on any day on which the National Weather Service has issued a Red Flag Warning as applicable to the Site.

4. Section 6, Subsection D, is amended as follows:

D. Construction; Commercial Operation. Promptly upon receipt of the Notice to Proceed to construction from City, Provider shall commence construction of the System, and shall cause the submission of final electrical clearance to the Distribution Utility prior to the net energy metering (NEM) deadline which is set for 11:59 PM local time on April 14, 2026 (the “ NEM Submission Deadline”). Provider shall cause complete installation and start-up of Commercial Operation thereof on or before the date as indicate d in Attachment C in Exhibit F (the “Commercial Operation Deadline”). The Commercial Operation Deadline shall be on or prior to June 15, 2026 . Prior to declaring Commercial Operation, Provider shall achieve the following:

1) Effect the execution, in coordination with City, of all agreements required for interconnection of the System with the Distribution Utility, including, without limitation, the Interconnection Agreement and net metering agreement if applicable; and

2) Ensure that all necessary connections and equipment are installed in compliance with all applicable codes and standards, and that Provider has procured or caused the complete installation of all necessary equipment and protection devices to enable delivery of Solar Facility Output and the Battery Systems Output from the Delivery Point to City’s facilities.

3) Obtain or cause to be obtained all necessary Permits, entitlements, contracts and agreements required for the operation and maintenance of the System and the sale and delivery of Solar Facility Output and the Battery Systems Output to City.

4 Revised September 2024
4) Provide written confirmation that (i) all required commissioning has been completed; (ii) City and its agents have been provided access to the monitoring data for the System at the level required by this Agreement; and (iii) all closeout activities outlined in Section 7 of Exhibit F have been completed.

5. Section 17, Subsection A, is amended as follows:

A. Indemnity. To the fullest extent provided for by law, each Party (“Indemnifying Party”) agrees to indemnify, defend and hold harmless the other Party, its directors, officers, employees, and agents (each, an “Indemnified Party”) from and against any and all claims, whether or not involving a third-party claim, including demands, actions, damages, loss, costs, expenses, and attorney’s fees (collectively, “Indemnity Claims”), arising out of or resulting from any breach, negligent act, error or omission or intentional misconduct by the Indemnifying Party or its trustees, directors, officers, employees, contractors, subcontractors or agents under the terms of this Agreement; provided, however, that the Indemnifying Party will not have any obligation to indemnify the Indemnified Party from or against any Indemnity Claims to the extent caused by, resulting from, relating to or arising out of the negligence or intentional misconduct of an Indemnified Party or any of its directors, officers, employees or agents.

Additionally, the City shall indemnify, defend and hold harmless all Provider Indemnified Parties from and against any and all Indemnity Claims arising out of or resulting from the existence at, on, above, below or emanating from the Site of any Pre-Existing Environmental Condition that has or will have a material adverse effect on Provider’s rights, entitlement, obligations or costs under this Agreement, including any subsequent discovery that the remediation activities conducted and completed by the City pursuant to the Solano County Department of Resource Management No Action Letter dated as of February 11, 2015 were incomplete or there is otherwise noncompliance with applicable environmental laws. An indemnity under this provision shall be reduced proportionally to the extent the Indemnity Claims arise due to Provider’s deliberate failure to comply with terms of this Agreement, or Provider engages in illegal activity.

If an Indemnified Party determines that it is entitled to defense and indemnification under this Section, such Indemnified Party shall promptly notify the Indemnifying Party in writing of the Indemnity Claim and provide all reasonably necessary or useful information, and authority to settle and/or defend Indemnity Claim. Defense and indemnification provided by the Indemnifying Party under this Section shall be provided with legal counsel reasonably agreed to by the Identified Party. No settlement that would impose costs or expense upon the Indemnified Party shall be made without such Party’s written consent.

6. Section 17, Subsection B, Item 1 is amended as follows:

1) Provider Insurance. At all times during the term of the PPA, and any necessary extension thereof for removal of the System from the Site, Provider and all subcontractors, shall obtain, maintain and keep in full force and effect the following insurance for coverage of 5 Revised September 2024
all obligations and associated activities under this Agreement, including but not limited to the use and occupancy of the Site, the business operated by the City thereon, and the construction, installation, operation, maintenance and repair of the System, in the amounts, and with the conditions required, as set forth herein , provided that the limits set forth herein may be satisfied through a combination of primary and excess policies .

Each policy required in (b)(c)(d) below shall include an additional insured endorsement in favor of City with an additional insured endorsement for both ongoing and completed operations as it pertains to (b) and shall include an endorsement specifying that such coverage is primary and non -contributory as to any other coverage available to the additional insured. Provider shall, except as otherwise set forth in Section 17.B.1.e below, within thirty (30) days of the Effective Date of this Agreement and annually thereafter or as requested by City, provide certificates of insurance and endorsements demonstrating compliance with the requirements of this Section.

a. Workers’ Compensation Insurance for Provider’s employees to the extent of statutory limits and Occupational Disease and Employer’s Liability Insurance for not less than $1,000,000 per occurrence.
b. Commercial General Liability Insurance with a $2,000,000 per occurrence and $5,000,000 aggregate limit of liability for Bodily Injury, Personal and Advertising Injury and Property Damage Liability, including coverage for Contractual Liability and Products and Completed Operations Liability.
c. Automobile Liability Insurance with limits not less than: Bodily Injury coverage at $2,000,000 each accident, and Property Damage coverage at $2,000,000 each accident.
d. Excess Liability Insurance in an aggregate amount of not less than $5,000,000 providing greater limits of insurance to Provider ’s Employer ’s Liability, Commercial General Liability and Automobile Liability Insurance which also shall not be more restrictive than coverage provided by these policies. e. Builder’s Risk/Installation Floater Insurance in a sufficient amount to protect Provider’s property, materials, tools and other financial interests on the Project , to be obtained and with coverage in force no later than ten (10) days after the date of Notice to Proceed.
f. Professional Liability Insurance with limits not less than $1,000,000 per claim, with a two -year tail, solely to the extent and for such time as Provider or any Subcontractor is actively engaged in work with professional liability exposure.

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6 Revised September 2024

7. Schedule 1 – System and Premises Description is amended as follows:

A. Premises
Physical Address:

Parcel Number:

Waterman Treatment Plant
2900 Vista Grande Circle, Fairfield, CA 95434
Site diagram attached as Attachment A: ☒ Yes ☐ No
Name of Mortgagee (lender): Not Applicable
Gross acreage of Premises:

Acreage to be used for System:

Refer to Site diagram
B. Description of Solar System
Type: Fixed-Tilt Ground Mount Solar PV System
paired with a Battery Energy Storage System
(BESS)
Solar System Size: 1,785 kW (DC) (this is an estimate (and not a guarantee) of the System size; Seller may update
the System Size prior to the Commercial
Operation Date.)
Module: The installation consists of (3010) QCells,
595W Photovoltaic Modules
Inverter: Chint SCH275KLT-DO/US-800-36 250W AC
output, UL1741 listed,grid tied inverters
Mounting System: Fixed-Tilt Terrasmart Racking

[Remainder of Page Intentionally Left Blank]

7 Revised September 2024

8. Exhibit A – Definitions is amended as follows:

1. “Annual Production Estimate ” shall mean, for the Solar Facility, the estimated energy production for a Contract Year as set forth in Exhibit B.

2. “Applicable Law ” shall mean, with respect to any person, any law, statute, rule, regulation, ordinance, treaty, order, decree, judgment, decision, holding, injunction, registration, license, guideline, Governmental Approval, consent or requirement of any Governmental Authority having jurisdiction over such person or its property, as any of the foregoing may be amended from time-to-time, and any corresponding provisions of any successor to the foregoing, together any rules or regulations promulgated under su ch successor.

3. “Assignment” shall have the meaning as defined in Section 19(A).

4. “Authorities Having Jurisdiction ” shall mean the governmental organization, office or individual responsible for approving equipment, an installation or a procedure.

5. “Battery Energy Storage System ” (or “Battery Systems”) shall mean an energy storage system with the minimum nameplate power and energy capacity as shown in Exhibit F.

6. “Battery Systems Energy Shortfall Amount ” shall mean an amount equal to the product of: (i) the Battery Systems Guarantee Rate, multiplied by (ii) the number of hours that one hundred percent (100%) of the nameplate power capacity of the Battery Systems was not available during the Measurement Period.

7. “Battery Systems Output ” shall mean the total quantity of all actual electrical energy discharged by the Battery Systems as measured in kWhac by a Meter installed in close proximity to the Delivery Point. Output does not include the Green Attributes, Environmental Financial Incentives, RECs or REC Reporting Rights.

8. “Battery Systems Services ” shall mean generating electricity bill cost savings for City through storage and discharge of electrical energy on and from the Battery Systems in accordance with Section 11(B).

9. “Battery Systems Guarantee Rate” means as defined in Exhibit C.

10. “City Conditions Precedent” shall have that meaning as set forth in Section 6(A) of the Agreement.

11. “City Permits” shall have that meaning as set forth in Section 5(C) of the Agreement. 8 Revised September 2024

12. “Conditions Precedent Deadline” shall have that meaning as set forth in Section 6(C) of the Agreement.

13. “Contract Year” shall mean a period of twelve (12) consecutive months (except in the case of the first Contract Year which may be longer) with the first Contract Year commencing on the Commercial Operation Date and each subsequent Contract Year commencing on the anniversary of the first day of the first month following the Commercial Operation Date.

14. “Commercial Operation” shall mean that (i) the Project is operating and able to produce and deliver Energy to City pursuant to the terms of this Agreement; (ii) Provider has received all local, state and federal Permits and other approvals as may be required by Law for the construction, operation and maintenance of the Project, including approvals, if any, required under the California Environmental Quality Act for the Project and related interconnection facilities.

15. “Commercial Operation Date” shall mean the date on which Provider achieves Commercial Operation for the Project.

16. “Commercial Operation Deadline” shall have that meaning as set forth in Section 6(E) of this Agreement.

17. “Days” shall mean calendar days, unless otherwise specified.

18. “Delay Liquidated Damages” shall mean the daily rate payable by the Provider to City for unexcused delays past the Commercial Operation Deadline or if submission of final electrical clearance has not occurred on or before 11:59 PM local time on April 14, 2026, in each case as outlined in Section 6(D).

19. “Delivery Point” shall mean the Energy delivery point within Site’s electrical system on City’s side of the Site’s Distribution Utility meter, as designated by the physical interface of the System with the Site’s electrical system.

20. “Distribution Utility” shall mean the investor owned, public, or private utility or electric utility having jurisdiction over the interconnection of the Systems.

21. “Distribution Utility Upgrades” shall mean that scope of work and associated costs that the Distribution Utility requires on the Distribution Utility side of the Distribution Utility meter in order for the System to interconnect to the Distribution Utility system.

9 Revised September 2024

22. “Energy” shall mean electrical energy measured in kWhac.

23. “Energy Shortfall Amount” shall mean an amount equal to the product of: (i) the Output Guarantee Rate, multiplied by (ii) the difference between the delivered Output for such Measurement Period and the Output Guarantee for such Measurement Period.

24. “Environmental Financial Incentives” shall mean each of the following financial rebates and incentives that is in effect as of the Effective Date: (i) investment tax credits associated with the development, construction, ownership or operation of the System, accelerated depreciation, and other financial incentives in the form of credits, reductions or allowances associated with the System that may be applied to reduce any state or federal income taxation obligation, and (ii) the right to claim federal incom e tax credits under Sections 26 or 48 of the Internal Revenue Code or any state tax law or income tax deductions with respect to the System under the Internal Revenue Code or any state tax law. Environmental Financial Incentives do not include Green Attributes.

25. “Expiration Date” shall mean the last day of the month that follows the twenty-fifth (25th) annual anniversary of the Commercial Operation Date.

26. “Force Majeure” shall mean any event or circumstances beyond the reasonable control of and without the fault or negligence of the Party claiming Force Majeure, which cannot reasonably be avoided, mitigated or cured through the reasonable and diligent efforts of the Party claiming Force Majeure. It shall include, without limitation, interruption or delay of the construction of the System or failure or interruption of the production, delivery or acceptance of electricity due to: (i) natural phenomena, such as storms, hurricanes, floods, lightning, volcanic eruptions and earthquakes; (ii) explosions or fires arising from lightning or other causes unrelated to the acts or omissions of the Party seeking to be excused from performance; (iii) acts of war or public disorders, civil disturbances or riots, insurrection, sabotage, epidemic, terrorist acts, or rebellion; (iv) action by a Governmental Authority resulting in a moratorium on the activities related to this Agreement; and (v) the inability of one of the Parties, despite its reasonable efforts, to obtain, in a timely manner, any Permit necessary to enable the affected Party to fulfill its obligations in accordance with this Agreement, provided that the delay or non-obtaining of such Permit is not attributable to the Party in question and that such Party has exercised due diligence to obtain such Permit. Force Majeure will not be based on (i) City’s inability to use Energy purchased hereunder, (ii) Provider’s ability to sell Energy at a price greater than the price of Energy under this Agreement, or (iii) City’s voluntary or involuntary shutting down or closing of the facilities located at the Property. Economic hardship of either Party shall not constitute Force Majeure.

27. “Governmental Authority” shall mean the government of the United States of America, any other nation or any political subdivision thereof, whether state or local, and any agency, authority, instrumentality, regulatory body, court, central bank or other entity exercising executive, legislati ve, judicial, taxing, regulatory or administrative powers or 10 Revised September 2024
functions of or pertaining to government (including any supra -national body exercising such powers or functions, such as the European Union or the European Central Bank).

28. “Governmental Approvals” shall mean any notices to, reports or other filings to be made with, or any consents, registrations, permits or authorizations to be obtained from, any Governmental Authority.

29. “Green Attributes” shall mean any and all credits, benefits, emissions reductions, offsets and allowances, howsoever entitled, attributable to the generation of Output from the System, and its displacement of conventional energy generation, that is in effect as of the Effective Date or may come into effect in the future. Green Attributes include but are not limited to Renewable Energy Certificates, as well as: (i) any avoided emissions of pollutants to the air, soil or water such as sulfur oxides (SOx), nitrogen oxides (NOx), carbon monoxide (CO) and other pollutants; (ii) any avoided emissions of carbon dioxide (CO2), methane (CH4), nitrous oxide, hydrofluorocarbons, perfluorocarbons, sulfur hexafluoride and other greenhouse gases (GHGs) that have been determined by the United Nations Intergovernmental Panel on Climate Change, or otherwise by law, to contribute to the actual or potential threat of altering the Earth’s climate by trapping heat in the atmosphere; and (iii) the reporting rights to these avoided emissions, such as REC Reporting Rights. Green Attributes do not include (i) any energy, capacity, reliability or other power attributes from the System, (ii) Environmental Financial Incentives, (iii) fuel- related subsidies or “tipping fees” that may be paid to Provider to accept certain fuels, or local subsidies recei ved by the generator for the destruction of particular preexisting pollutants or the promotion of local environmental benefits or (iv) emission reduction credits encumbered or used by th e System for compliance with local, state or federal operating and/or air quality Permits.

30. “Hazardous Materials ” means any hazardous or toxic material, substance or waste, including petroleum, petroleum hydrocarbons or petroleum products, petroleum by - products, radioactive materials, asbestos or asbestos -containing materials, gasoline, diesel fuel, pesticides, radon, urea formaldehyde, mold, lead or lead-containing materials, polychlorinated biphenyls; and any other chemicals, materials, substances or wastes in any amount or concentration which are regulated under or for which liability can be imposed under any Applicable Law.

31. “Insolation” shall mean the amount of solar energy measured in watts per square meter (W/m2) falling on a particular location during a specific time, as published by the National Renewable Energy Laboratory.

32. “Interconnection Agreement” shall mean an agreement entered into by and between City and the Distribution Utility which agreement shall provide for (i) each System to be interconnected with the Distribution Utility’s electricity distribution system, (ii) for energy to flow from each System to such system and (iii) for energy to flow from such system to the Site, as applicable, under the provisions of all applicable Distribution Utility’s tariffs. 11 Revised September 2024

33. “Internal Revenue Code” shall mean the Internal Revenue Code of 1986, as amended.

34. “kWac” shall mean kilowatt alternating current.

35. “kWdc” shall mean kilowatt direct current.

36. “kWhac” shall mean kilowatt-hour alternating current.

37. “Notice to Proceed” shall mean as defined in Section 6(C).

38. “Outage” shall mean as defined in Section 4(I).

39. “Output” or “Solar Facility Output” shall mean the total quantity of all actual electrical power generated by the Solar Facilities as measured by a Meter in close proximity to the Delivery Point measured in kWhac. Output does not include the Green Attributes, Environmental Financial Incentives, RECs or REC Reporting Rights.

40. “Output Guarantee Rate” shall mean as defined in Exhibit B.

41. “Parallel Energy Services ” shall mean to remain interconnected to and receive grid services.

42. “Permits” shall mean all government permits and approvals, regulatory or otherwise required for the construction, installation, completion and operation of the System.

43. “Person” shall mean any individual, corporation, partnership, joint venture, association, joint stock company, trust, trustee, estate, limited liability company, unincorporated organization, real estate investment trust, government or any agency or political subdivision thereof, or any other form of entity.

44. “Power Price” shall mean the per kWhac rate(s) as set forth on Exhibit B

45. “Pre-Existing Environmental Conditions” means any of: (i) a violation of, breach of or non- compliance with any environmental laws with respect to the Site that first existed, arose or occurred on or prior to Provider receipt of Notice to Proceed, or (ii) the presence or release of, or exposure to, any Hazardous Materials at, to, on, in, under or from the Site that first existed, arose or occurred on or prior to Provider receipt of Notice to Proceed the Site.
12 Revised September 2024

46. “Project” shall have that meaning as set forth in the Recitals of this Agreement.

47. “Provider Conditions Precedent” shall have that meaning as set forth in Section 6(B) of the Agreement.

48. “Provider Permits” shall have that meaning as set forth in Section 5(C) and Exhibit E of the Agreement.

49. “RECs” or “ Renewable Energy Certificates ” shall mean renewable energy certificates related to and representing Green Attributes (also known as green tags, renewable energy credits, or tradable renewable certificates), which are tradable environmental commodities in the United States and represen t 1 megawatt -hour (MWh) of electricity generated from an eligible renewable energy resource. These certificates can be sold and traded and the owner of the REC can claim to have purchased renewable energy.

50. “REC Reporting Rights” shall mean the right of a REC purchaser to report the ownership of accumulated RECs in compliance with federal or state law, if applicable, and to a federal or state agency or any other Party at the REC purchaser’s discretion, and include without limitation those REC Reporting Rights accruing under Section 1605(b) of the Energy Policy Act of 1992 and any present or future federal, state, or local law, regulation or bill, and international or foreign emissions trading program.

51. “Supervisory Control and Data Acquisition ” or “ SCADA” shall mean the system that monitors, communicates with, and controls devices throughout the System.

52. “Site” shall mean the portion of City’s real property on which a System is to be located pursuant to this Agreement, as described in Schedule 1 attached hereto.

53. “Solar Facility ” means each solar photovoltaic generation plant, together with all necessary inverters, ancillary equipment with a target installation size expressed in kWdc and kWac as shown in Exhibit F to be installed at the Site and as described in Schedule 1 attached hereto.

54. “Termination Value” shall equal the amount shown in Exhibit D for each Contract Year.

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13 Revised September 2024

9. Exhibit C – Battery Systems Guarantee Rate is amended as follows:

Exhibit C – Battery Systems Guarantee Rate

The Parties acknowledge the below table shall apply to the System only if the System achieves the NEM 2 Submission Deadline.

Contract Period,
Months
Contract
Year Guaranteed Cycles Battery Systems Guarantee Rate
1-12 1 320 $40 /cycle
13-24 2 300 $40 / cycle
25-36 3 288 $40 / cycle
37-48 4 282 $40 / cycle
49-60 5 276 $40 / cycle
61-72 6 271 $40 / cycle
73-84 7 264 $40 / cycle
85-96 8 258 $40 / cycle
97-108 9 253 $40 / cycle
109-120 10 248 $40 / cycle
121-132 11 244 $40 / cycle
133-144 12 239 $40 / cycle
145-156 13 234 $40 / cycle
157-168 14 231 $40 / cycle
169-180 15 227 $40 / cycle

Net-Billing (NEM 3) Scenario.

Contract Period,
Months
Contract
Year Guaranteed Cycles Battery Systems Guarantee Rate
1-12 1 328 $39 /cycle
13-24 2 306 $39 / cycle
25-36 3 295 $39 / cycle
37-48 4 288 $39 / cycle
49-60 5 282 $39 / cycle
61-72 6 277 $39 / cycle
73-84 7 270 $39 / cycle
85-96 8 264 $39 / cycle
97-108 9 259 $39 / cycle
109-120 10 254 $39 / cycle
121-132 11 249 $39 / cycle
133-144 12 244 $39 / cycle
145-156 13 239 $39 / cycle
157-168 14 236 $39 / cycle
169-180 15 233 $39 / cycle
14 Revised September 2024

12. Exhibit D – Termination Values is amended as follows:

Exhibit D – Termination Values

1) 40% ITC Scenario (qualifying for the 10% ITC Adder)

Contract Period,
Months
Contract Year Termination Value
1-12 1 $11,300,685.28
13-24 2 $10,019,676.53
25-36 3 $8,510,538.38
37-48 4 $7,202,012.47
49-60 5 $6,013,511.39
61-72 6 $4,812,914.09
73-84 7 $4,542,259.34
85-96 8 $4,363,530.83
97-108 9 $4,180,428.21
109-120 10 $3,991,785.22
121-132 11 $3,797,371.35
133-144 12 $3,595,984.08
145-156 13 $3,389,261.25
157-168 14 $3,176,017.84
169-180 15 $2,955,984.31
181-192 16 $2,727,936.63
193-204 17 $2,493,433.00
205-216 18 $2,251,262.85
217-228 19 $2,001,110.97
229-240 20 $1,741,724.60
241-252 21 $1,474,575.79
253-264 22 $1,199,314.42
265-276 23 $914,713.82
277-288 24 $619,485.46
289-300 25 $315,009.12

15 Revised September 2024
2) Standard 30% ITC Scenario

Contract Period,
Months
Contract Year Termination Value
1-12 1 $11,269,070.71
13-24 2 $10,157,758.70
25-36 3 $8,804,540.45
37-48 4 $7,664,220.24
49-60 5 $6,648,241.30
61-72 6 $5,620,058.02
73-84 7 $5,314,340.11
85-96 8 $5,106,383.81
97-108 9 $4,891,063.37
109-120 10 $4,670,361.35
121-132 11 $4,442,908.24
133-144 12 $4,208,423.62
145-156 13 $3,965,494.79
157-168 14 $3,716,015.89
169-180 15 $3,458,593.61
181-192 16 $3,192,900.01
193-204 17 $2,917,495.30
205-216 18 $2,634,178.61
217-228 19 $2,341,524.60
229-240 20 $2,039,149.81
241-252 21 $1,725,578.46
253-264 22 $1,403,452.78
265-276 23 $1,070,397.82
277-288 24 $725,966.62
289-300 25 $368,638.77

16 Revised September 2024

13. EXHIBT F – General Conditions and Technical Specifications, Section 2, Subsection “Physical Site Investigation & Project Feasibility Assessment” is amended as follows:

Installer shall read and become knowledgeable with all documentation available concerning the Project and visit the Sites to assess its conditions and logistics, including but not limited to all Distribution Utility interconnection related requirements. Installer shall conduct feasibility and configuration assessments, environmental assessments, and all other inspections of the Sites to determine that the Sites can support the installation and interconnection of the Systems.

Installer must visit the Sites to ascertain site conditions, accuracy of provided drawings and feasibility of design. Installer shall be responsible to ensure that each Site’s soil conditions and terrains are favorable for the Project (in Installer’s sole discretion).

14. EXHIBIT F – General Conditions and Technical Specifications, Section 3.1.3, Item (e) is amended as follows:

Provider shall provide grass cutting services at the Site at least once per calendar year between May 1st and June 30th following the Commercial Operation Date for purposes of weed abatement and vegetation control, provided that Provider shall not cut grass or otherwise provide vegetation control services on any day on which the National Weather Service has issued a Red Flag Warning as applicable to the Site.

15. EXHIBIT F – General Conditions and Technical Specifications, ATTACHMENT A – Preliminary Design is replaced in its entirety by Attachment 1 to this Amendment.

16. EXHIBIT F – General Conditions and Technical Specifications, ATTACHMENT B – Site Assessment Table is replaced in its entirety by Attachment 2 to this Amendment.

17. EXHIBIT F – General Conditions and Technical Specifications, ATTACHMENT C – Project Schedule is replaced in its entirety by Attachment 3 to this Amendment.

18. EXHIBIT F – General Conditions and Technical Specifications, ATTACHMENT D – Commissioning Schedule is replaced in its entirety by Attachment 4 to this Amendment.

19. EXHIBIT F – General Conditions and Technical Specifications, ATTACHMENT F – Major Equipment is replaced in its entirety by Attachment 5 to this Amendment.

[Remainder of Page Intentionally Left Blank]

17 Revised September 2024
Except as specifically set forth herein, all terms and conditions of the AGREEMENT between the CITY and ONYX, dated August 26, 2024, shall remain in full force and effect.

In Witness whereof, the parties through their authorized representatives, have affixed their signature.

CITY OF FAIRFIELD
a municipal corporation (CITY)

By
David Gassaway, City Manager

Onyx Development Group LLC.

By
Patricia L. Rollin, Authorized Signatory

ATTACHMENT 1
EXHIBIT F – General Conditions and Technical Speciﬁcations, ATTACHMENT A – Preliminary Design
STAMP:

PROJECT:
1301 Cap. O TX Hwy S #B315
Austin, TX 78746
www.holtrenewables.com
C:\Users\samuel.sherman\onedrive - holt group\Desktop\city of fairfield, ca\03 - design\3.3 drawings\3.32 Sheets\WI101 SITE PLAN.dwg 8/13/25 - 3:36pm

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024
SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET
KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765

GENERAL SHEET NOTES

1. ALL DIMENSIONS ARE APPROXIMATE AND MUST BE FIELD
VERIFIED.

2. CONDUIT AND PULL BOXES SHALL BE INSTALLED IN
ACCORDANCE WITH THE FOLLOWING CEC ARTICLES: 342.26
FOR IMC, 344.26 FOR RMC, 352.26 FOR PVC, 353.26 FOR
HDPE, 358.26 FOR EMT CONDUIT, AND 314.28-314.30 FOR
PULLBOXES.

3. IMPACT DRIVERS ARE NOT APPROVED FOR USE ON
INVERTERS OR WIRING BOXES.

SHEET KEYNOTES

1. INVERTERS AND OTHER PV EQUIPMENT AT ARRAY SHALL BE
RACK MOUNTED.

2. SWITCHGEAR, TRANSFORMER, AND BESS ARE TO BE PAD
MOUNTED.

3. THIS AREA HAS BEEN DESIGNATED AS A WETLAND
MITIGATION ZONE. ALL WORK FOR THE SCOPE OF THIS

PROJECT IS TO AVOID THIS AREA AND LEAVE IT
UNDISTURBED.

4. NEW OVERALL SITE METER FOR THE TESLA SITE

CONTROLLER AND OVERALL OUTPUT METER SHALL BE WALL
MOUNTED NEAR INTERCONNECTION.

SITE PLAN
WI101.1
SCALE: 1/64" = 1'-0"
SITE PLANA1
TRUE
NORTH
SCALE: NTS
SITE PLAN - SUMMARYD3

PV SOLAR SYSTEM & BESS SUMMARY
(TOTAL MODULE COUNT) MODULE MANF. & MODEL NUMBER / STC DC RATING (3000) QCELLS Q.PEAK DUO XL-G11S.3/BFG 595, 595W PLUS (10) DUMMY MODULES
TOTAL STRINGS OF MODULES PER STRING 120 STRINGS OF 25 MODULES

PV ARRAY RACKING STYLE / MANUFACTURER AND MODEL FIXED-TILT GROUND MOUNT / TERRASMART GLIDE AGILE TOTAL STC DC SYSTEM SIZE 1785.00 kW
(TOTAL INVERTER COUNT) INVERTER MANF. AND MODEL ( 5) CHINT CPS SCH275KLT-DO/US-800-36, 250kW AC INVERTER CEC EFFICIENCY 98.5%
SITE LATITUDE 38° 16' 33" N

ARRAY AZIMUTH / MODULE TILT
180°/ 20°
ASHRAE DESIGN TEMPERATURE EXTREME MIN. / 2% HIGH -3°C/36°C BESS UNIT TESLA MEGAPACK 2 XL 4HR(448.8kW/1795.2kWh)
INTERCONNECTION VOLTAGE 480 VAC 3ɸ
INTERCONNECTION OCPD RATING 3000A

INTERCONNECTION TYPE LINE-SIDE CONNECTION AT SOLAR READY BREAKER

PV ARRAY A
(1202) MODULES (2 DUMMIES)
(2) CHINT INVERTERS, INV.01-02
(1) CHINT AC COMBINER, ACC.01
(FIXED-TILT GROUND MOUNT)

PV EQUIPMENT AT INTERCONNECTION
(1) AC UTILITY DISCONNECT, ACD.01
(PAD MOUNTED)
(1) SITE METER
(1) OUTPUT METER
(WALL MOUNTED)

PV & BESS EQUIPMENT YARD
(1) PV TRANSFORMER, PVXFMR.01
(1) TESLA MEGAPACK 2 XL BESS UNIT
(1) AC SWITCHGEAR, SWGR.01
(1) PV METER
(1) AUXILIARY POWER TRANSFORMER
(1) TESLA SITE CONTROLLER
(1) GELI EMS
(1) ALSOENERGY REMOTE ENCLOSURE FOR BESS
(PAD MOUNTED)
UG AC CONDUIT RUN (TYP.)
1 2
2 (3) EXISTING CONDUITS IN JOINT TRENCH;

FIBER, WATER, & ELECTRICAL

JOINT TRENCH CROSSING

WETLAND MITIGATION ZONE

TO BE AVOIDED
3 EXISTING 12' PAVED ACCESS PATH

PV ARRAY B
(1808) MODULES (8 DUMMIES)
(3) CHINT INVERTERS, INV.03-05
(1) CHINT AC COMBINER, ACC.02
(FIXED-TILT GROUND MOUNT)
1 4
PV SWITCHGEAR SWGR.02
(PAD MOUNTED)
2 GENERATOR (E)
RELOCATED 12"

WATER LINE

UTILITY

TRANSFORMER

MAIN SERVICE

SWITCHBOARD

PROFESSIO
NA

L ENGINEER
E19765
STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024

SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET

KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765

GENERAL SHEET NOTES

1. ALL DIMENSIONS ARE APPROXIMATE AND MUST BE FIELD
VERIFIED.

3. IMPACT DRIVERS ARE NOT APPROVED FOR USE ON
INVERTERS OR WIRING BOXES.

SHEET KEYNOTES

1. INVERTERS, DAS, MONITORING EQUIPMENT, AND OTHER PV
EQUIPMENT AT ARRAY SHALL BE RACK MOUNTED.

2. SWITCHGEAR, TRANSFORMER, AND BESS ARE TO BE PAD
MOUNTED.

3. THIS AREA HAS BEEN DESIGNATED AS HAVING AQUATIC
RESOURCES THAT ARE TO BE PROTECTED. ALL WORK FOR

THE SCOPE OF THIS PROJECT IS TO AVOID THIS AREA AND
LEAVE IT UNDISTURBED. NO UNDERGROUND LINES ARE TO
BE RUN THROUGH THESE AREAS.

SITE PLAN -
ARRAY
WI101.2
SCALE: 1" = 40'-0"
SITE PLAN - ARRAYA1
TRUE
NORTH
PV SWITCHGEAR SWGR.02
(1) AC RECOMBINER
(PAD MOUNTED)

MONITORING RACK
(1) DAS ENCLOSURE, COMM.01
(1) CHINT PLC ENCLOSURE, PLC.01
(1) 5kVA AUX. TRANSFORMER
(1) AUX. POWER PANELBOARD
(1) NEMA3R SERVICE OUTLET
(RACK MOUNTED)
30' ACCESS GATE
INV.01, INV.02, ACC.01
2 PV ARRAY B
(1808) MODULES (8 DUMMIES)
(3) CHINT INVERTERS, INV.03-05
(1) CHINT AC COMBINER, ACC.02
(FIXED-TILT GROUND MOUNT)
1 INV.03, INV.04, INV.05, ACC.02
1 1
UG AC
CONDUIT RUN (TYP.)

AQUATIC RESOURCES AREA

TO BE AVOIDED
3 AQUATIC RESOURCES AREA

TO BE AVOIDED
3 DRAINAGE WITH HYDROPHYTIC VEGETATION
& 25' VEGETATED BUFFER

TO BE AVOIDED
3 (2) UP X (25) WIDE ROW
(2) UP X (25) WIDE ROW
(2) UP X (100) WIDE ROW

AQUATIC RESOURCES AREA

TO BE AVOIDED
3 (3) EXISTING CONDUITS IN JOINT TRENCH;

FIBER, WATER, & ELECTRICAL

JOINT TRENCH CROSSING

NEW CHAIN-LINK FENCE
APPROX. 1330'

NEW CHAIN-LINK FENCE
APPROX. 1710'

PV ARRAY A
(1202) MODULES (2 DUMMIES)
(2) CHINT INVERTERS, INV.01-02
(1) CHINT AC COMBINER, ACC.01
(FIXED-TILT GROUND MOUNT)
1 (2) UP X (50) WIDE ROW
(2) UP X (75) WIDE ROW
(2) UP X (100) WIDE ROW
(2) UP X (100) WIDE ROW
(2) UP X (75) WIDE ROW

AQUATIC RESOURCES AREA

TO BE AVOIDED
3 (2) UP X (63) WIDE ROW
(2) UP X (50) WIDE ROW
(2) UP X (63) WIDE ROW
(2) UP X (13) WIDE ROW
(2) UP X (63) WIDE ROW
(2) UP X (25) WIDE ROW
(2) UP X (50) WIDE ROW
DUMMY MODULE (TYP. OF 10)
30' ACCESS
GATE
15 FOOT BUFFER
(2) UP X (75) WIDE ROW
(2) UP X (38) WIDE ROW
(2) UP X (13) WIDE ROW
16' SETBACK (TYP.)
16' SETBACK (TYP.)
(2) UP X (38) WIDE ROW UG DC CONDUIT RUN (TYP.)

WEATHER STATION
A1
WI201.1
A4
WI201.1
WI201.1
C1
1 12' ROW-TO-ROW SPACING (TYP.)
WI201.1
C4

PROFESSIO
NA

L ENGINEER
E19765
STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024

SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET

KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765

GENERAL SHEET NOTES

1. ALL DIMENSIONS ARE APPROXIMATE AND MUST BE FIELD
VERIFIED.

3. IMPACT DRIVERS ARE NOT APPROVED FOR USE ON
INVERTERS OR WIRING BOXES.

SHEET KEYNOTES

1. SWITCHGEAR, TRANSFORMER, BESS, AND UTILITY
DISCONNECT ARE TO BE PAD MOUNTED.

2. AUXILIARY PANELBOARD, TESLA SITE CONTROLLER, AND
GELI EMS TO BE RACK MOUNTED ON PAD.

3. NEW OVERALL SITE METER FOR THE TESLA SITE

CONTROLLER AND OVERALL OUTPUT METER SHALL BE WALL
MOUNTED NEAR INTERCONNECTION.

4. EXISTING V-DITCH IN THIS AREA TO BE RELOCATED AND

REROUTED TO AVOID EQUIPMENT YARD BY THE CITY PRIOR
TO THE START OF CONSTRUCTION. VERIFY EXISTING
CONDITIONS IN FIELD.

SITE PLAN - POI
WI101.3
SCALE: 1/16" = 1'-0"
SITE PLAN - POIA1
TRUE
NORTH

INTERCONNECTION AT MAIN

SWITCHBOARD IN ELECTRICAL

ROOM UTILIZE CONDUITS

DESIGNATED FOR SOLAR
RELOCATED 12"

WATER LINE
10' WATER LINE

SETBACK

OUTPUT METER

SITE METER

UTILITY DISCONNECT
(ACD.01)

PV & BESS

SWITCHGEAR
(SWGR.01)
TESLA MEGAPACK 2 XL

PV TRANSFORMER
(PVXFMR.01)

AUXILLARY PANELBOARD,

ALSOENERGY REMOTE

ENCLOSURE FOR BESS,

TESLA SITE CONTROLLER,

GELI EMS
EXISTING 12'

PAVED ROAD

RETAINING WALL AT NORTH FENCE LINE,

STRUCTURAL/CIVIL SHEETS FOR MORE INFORMATION
REQUIRED 10'

ACCESS PATH
10' ACCESS GATE

AC POWER CONDUIT

DATA CONDUIT

BESS PAD
(33'-3" X 7'-2")

EQUIPMENT PAD
(14'-10" X 13'-3")
1 2
1 13
1 PV POWER CONDUIT

UTILITY TRANSFORMER

FOR REFERENCE
EQUIPMENT YARD FENCE (140')
A1
WI201.3
A3
WI201.3

APPROXIMATE LOCATION OF EXISTING IRRIGATION

HANDHOLE THAT IS TO BE RELOCATED ALONG

WITH IRRIGATION LINES THAT ARE TO BE

RELOCATED BY THE CITY PRIOR TO THE START OF
THIS PROJECT'S CONSTRUCTION. VERIFY EXISTING
CONDITIONS IN FIELD.

REQUIRED 8'

MAINTENANCE AREA
10'

EXISTING V-DITCH
(TO BE RELOCATED) 4

PROFESSIO
NA

L ENGINEER
E19765
STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024
SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET
KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765

GENERAL SHEET NOTES

1. ALL DIMENSIONS ARE APPROXIMATE AND MUST BE FIELD
VERIFIED.

SHEET KEYNOTES

EQUIPMENT PLAN
WI102
Scale: 1/2" = 1'-0"
EQUIPMENT PLAN - SWGR.02A1
TRUE
NORTH
TRUE
NORTH
3' 3'
3'
MCB.02
ACRC.01

AUXILIARY POWER PANELBOARD
TESLA MEGAPACK 2 XL
SWGR.01
PVXFMR.01

GELI EMS

AUXILIARY POWER

PANELBOARD
REQUIRED 3' FRONT CLEARANCE (TYP.)

AUXILIARY POWER XFMR

ALSOENERGY DAS ENCLOSURE

CHINT PLC ENCLOSURE
Scale: 3/8" = 1'-0"
EQUIPMENT PLAN - EQUIPMENT YARDC1
REQUIRED 8'

MAINTENANCE AREA
10' ACCESS GATE
EQUIPMENT YARD FENCE (140')

TESLA SITE CONTROLLER
REQUIRED 3' FRONT
CLEARANCE (TYP.)
MAINTAIN 10' CLEARANCE TO BESS

UNIT FROM ANY COMBUSTIBLE
VEGETATION PER CFC 1207.5.7
10' WATER LINE

SETBACK

RETAINING WALL AT NORTH FENCE LINE,

STRUCTURAL/CIVIL SHEETS FOR MORE INFORMATION

ALSOENERGY REMOTE

ENCLOSURE FOR BESS
R10'
8'
REQUIRED 10' ACCESS PATH; MAXIMUM 10% GRADE
SLOPE & 5% CROSS SLOPE PER TESLA REQUIREMENTS
3' 3' 3'
3'
C4
WI201.2
A5
WI201.2
C1
WI201.2
A1
WI201.2

PROFESSIO
NA
L

ENGINEER
E19765
STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024

SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET

KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765

CONDUIT PLAN -

PV ARRAY A
WI103.1
Scale: 1" = 20'-0"
CONDUIT PLAN - PV ARRAY AA1
TRUE
NORTH
UG DC STRING CONDUIT (INV.02)
(2) STRINGS
(1) 1" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.02)
(4) STRINGS
(1) 1-1/4" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.02)
(7) STRINGS
(1) 2" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.02)
(11) STRINGS
(1) 2" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.02)
(15) STRINGS
(1) 1-1/4" PVC40 (PV POWER)
(1) 2" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.01)
(22) STRINGS
(2) 2" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.01)
(14) STRINGS
(1) 1-1/4" PVC40 (PV POWER)
(1) 2" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.01)
(6) STRINGS
(1) 1-1/2" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.02)
(4) STRINGS
(1) 1-1/4" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.01)
(24) STRINGS
(1) 1" PVC40 (PV POWER)
(2) 2" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.02)
(20) STRINGS
(2) 2" PVC40 (PV POWER)

GENERAL SHEET NOTES

1. ALL DIMENSIONS ARE APPROXIMATE AND MUST BE FIELD
VERIFIED.

SHEET KEYNOTES
ACC.01 TO ACRC.01
(2) 3" PVC40 (PV POWER)
INV.02 TO ALSOENERGY DAS
(1) 1" PVC40 (DATA)

SPARE CONDUIT FUTURE SITE OWNER USE
(2) 2" PVC40 (SPARE)
N09 PULL BOX PLACED EVERY 200'
NO. 9 PULL BOX

FOR SPARE CONDUITS
NO. 9 PULL BOX

FOR SPARE CONDUITS

CONDUIT LEGEND

AC POWER
DATA

DC POWER
INTER-

CONNECTION
SPARE

PROFESSIO
NA

L ENGINEER
E19765
STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024

SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET

KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765

CONDUIT PLAN -

PV ARRAY B
WI103.2
Scale: 1" = 25'-0"
CONDUIT PLAN - PV ARRAY BA1
TRUE
NORTH
UG DC STRING CONDUIT (INV.03)
(2) STRINGS
(1) 1" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.03)
(6) STRINGS
(1) 1-1/2" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.03)
(10) STRINGS
(1) 2" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.03)
(15) STRINGS
(1) 1-1/2" PVC40 (PV POWER)
(1) 2" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.03)
(20) STRINGS
(2) 2" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.03)
(24) STRINGS
(1) 1" PVC40 (PV POWER)
(2) 2" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.04)
(2) STRINGS
(1) 1" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.04)
(10) STRINGS
(1) 2" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.03)
(24) STRINGS
(1) 1" PVC40 (PV POWER)
(2) 2" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.04)
(14) STRINGS
(1) 1-1/2" PVC40 (PV POWER)
(1) 2" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.04)
(1) STRINGS
(1) 1" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.04)
(2) STRINGS
(1) 1" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.04)
(3) STRINGS
(1) 1-1/4" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.04)
(6) STRINGS
(1) 1-1/2" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.05)
(1) STRINGS
(1) 1" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.05)
(3) STRINGS
(1) 1-1/4" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.05)
(6) STRINGS
(1) 1-1/2" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.05)
(10) STRINGS
(1) 2" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.05)
(14) STRINGS
(1) 1-1/4" PVC40 (PV POWER)
(1) 2" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.05)
(19) STRINGS
(2) 2" PVC40 (PV POWER)
UG DC STRING CONDUIT (INV.05)
(24) STRINGS
(1) 1" PVC40 (PV POWER)
(2) 2" PVC40 (PV POWER)
MCB.02 TO XFMR.01
(6) 4" PVC40 (PV POWER)

ALSOENERGY DAS TO PV METER
(1) 1" PVC40 (DATA)

SPARE CONDUIT FUTURE SITE OWNER USE
(2) 2" PVC40 (SPARE)
N09 PULL BOX PLACED EVERY 200'
ACC.01 TO ACRC.01
(2) 3" PVC40 (PV POWER)
INV.02 TO ALSOENERGY DAS
(1) 1" PVC40 (DATA)
ACC.02 TO ACRC.01
(2) 3" PVC40 (PV POWER)
INV.05 TO ALSOENERGY DAS
(1) 1" PVC40 (DATA)

WEATHER STATION TO

ALSOENERGY DAS
(1) 3/4" PVC40 (DATA)

GENERAL SHEET NOTES

1. ALL DIMENSIONS ARE APPROXIMATE AND MUST BE FIELD
VERIFIED.

SHEET KEYNOTES
ALSOENERGY DAS TO ACRC.01
(1) 3/4" PVC40 (AC POWER)
AUX XFMR TO ACRC.01
(1) 3/4" PVC40 (AC POWER)

CONDUIT LEGEND

AC POWER
DATA

DC POWER
INTER-

CONNECTION
SPARE

PROFESSIO
NA

L ENGINEER
E19765
STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024
SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET
KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765

GENERAL SHEET NOTES

1. ALL DIMENSIONS ARE APPROXIMATE AND MUST BE FIELD
VERIFIED.

SHEET KEYNOTES

CONDUIT PLAN -
POI
WI103.3
Scale: 1/4" = 1'-0"
CONDUIT PLAN - POIA1
TRUE
NORTH
Scale: 3/8" = 1'-0"
CONDUIT PLAN - EQUIPMENT YARDC1
MCB.02 TO XFMR.01
(6) 4" PVC40 (PV POWER) ALSOENERGY DAS

TO PV METER
(1) 1" PVC40 (DATA)
XFMR.01 TO SWGR.01
(7) 4" PVC40 (PV POWER)
BESS TO SWGR.01
(3) 3" PVC40 (BESS POWER)

BESS INTERFACE BAY TO TESLA SITE CONTROLLER
(1) 1" PVC40 (DATA, 24VDC)
SWGR.01 TO AUX.

POWER PANELBOARD
(1) 1-1/4" PVC40 (AUX POWER)
SWGR.01 TO ACD.01
(8) 4" PVC40 (PV & BESS POWER)

GELI EMS TO SITE METER
(1) 1" PVC40 (DATA)
SWGR.01 TO ACD.01
(8) 4" PVC40 (PV & BESS POWER)

GELI EMS TO OUTPUT METER
(1) 1" PVC40 (DATA)
ACD.01 TO INTERCONNECTION
(8) 4" RMC (PV & BESS POWER)

SITE METER TO MSB
(1) 3/4" EMT (DATA)

PV METER TO GELI EMS
(1) 1" PVC40 (DATA)

BESS METER TO GELI EMS
(1) 1" PVC40 (DATA)

SPARE CONDUIT FUTURE SITE OWNER USE
(2) 2" PVC40 (SPARE)
N09 PULL BOX PLACED EVERY 200'

CONDUIT LEGEND

AC POWER
DATA

DC POWER
INTER-

CONNECTION
SPARE
TRUE
NORTH

OUTPUT METER
TO ACD.01
(1) 3/4" PVC40 (DATA)

PROFESSIO
NA
L

ENGINEER
E19765
STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024

SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET

KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765

GENERAL SHEET NOTES

1. ALL DIMENSIONS ARE APPROXIMATE AND MUST BE FIELD
VERIFIED.

3. SHOCK HAZARD WARNING LABELS ON ALL ELECTRIC GEAR,
SEE A1/WP711.

SHEET KEYNOTES

SIGNAGE PLAN -
ARRAY
WI104.1
Scale: 1/16" = 1'-0"
SIGNAGE PLAN - ARRAYA1
TRUE
NORTH

1. DC DISCONNECT LABEL, SEE A1/WP710.

2. PLACARD MAP, SEE A4/WP710.

3. DC CIRCUIT WARNING ON DC CONDUIT, SEE A5/WP711.

4. AC BREAKER BOX LABEL, SEE D4/WP710.

5. AC PANELBOARD, SEE B1/WP711.

6. AC DISCONNECT, SEE D1/WP711.

7. MULTIPLE POWER SOURCES, SEE B3/WP711.

8. EQUIPMENT ID LABEL, SEE A1/WP712.

9. SHOCK HAZARD WARNING, SEE A1/WP711.

10. EPC MARK, SEE A3/WP711.

11. INTERCONNECTION, SEE B5/WP711.

INV.01, INV.02
ACC.01
1 3 98
4 5 98
INV.03, INV.04, INV.05
ACC.02
1 3 98
4 5 98
ACRC.015 98 102

AUXILIARY POWER PANELBOARD

AUXILIARY POWER XFMR

ALSOENERGY DAS ENCLOSURE

CHINT PLC ENCLOSURE
98 5

PROFESSIO
NA

L ENGINEER
E19765
STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024
SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET
KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765

1. ALL DIMENSIONS ARE APPROXIMATE AND MUST BE FIELD
VERIFIED.

3. SHOCK HAZARD WARNING LABELS ON ALL ELECTRIC GEAR,
SEE A1/WP711.

SHEET KEYNOTES

SIGNAGE PLAN -
POI
WI104.2

GENERAL SHEET NOTES
Scale: 1/4" = 1'-0"
SIGNAGE PLAN - POIA1
TRUE
NORTH
BESS
SWGR.01
PVXFMR.01
ACD.01

INTERCONNECTION AT (E) SOLAR READY SECTION
2 97 10 11
962 10
7 98
7 98 102
98 1. DC DISCONNECT LABEL, SEE A1/WP710.

2. PLACARD MAP, SEE A4/WP710.

3. DC CIRCUIT WARNING ON DC CONDUIT, SEE A5/WP711.

4. AC BREAKER BOX LABEL, SEE D4/WP710.

5. AC PANELBOARD, SEE B1/WP711.

6. AC DISCONNECT, SEE D1/WP711.

7. MULTIPLE POWER SOURCES, SEE B3/WP711.

8. EQUIPMENT ID LABEL, SEE A1/WP712.

9. SHOCK HAZARD WARNING, SEE A1/WP711.

10. EPC MARK, SEE A3/WP711.

11. INTERCONNECTION, SEE B5/WP711.

TESLA SITE CONTROLLER
98 OWNER SITE METER
98 AUXILIARY POWER PANELBOARD
985
TRUE
NORTH
Scale: 3/8" = 1'-0"
SIGNAGE PLAN - EQUIPMENT YARDC1

GELI EMS
98 ALSOENERGY REMOTE

ENCLOSURE FOR BESS
98 OVERALL OUTPUT METER
98 PROFESSIO
NA
L

ENGINEER
E19765
STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024
SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET
KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765

GENERAL SHEET NOTES

EQUIPMENT

ELEVATIONS
WI201.1
Scale: 1/2" = 1'-0"
EQUIPMENT ELEVATIONS - INVERTERS AT PV ARRAY AA1

1. DISPLAY A PERMANENT PLAQUE OR DIRECTORY PROVIDING

THE LOCATION OF THE UTILITY SERVICE DISCONNECTING

MEANS AND THE PHOTOVOLTAIC DISCONNECTING MEANS IF
NOT LOCATED AT THE SAME LOCATION.

2. ALL DIMENSIONS ARE APPROXIMATE AND MUST BE FIELD
VERIFIED.

3. ALL SOLAR PV EQUIPMENT SHALL HAVE A MINIMUM WORKING
CLEARANCE OF 36 INCHES IN FRONT AND 6 INCHES ON EACH
SIDE.

4. METERS SHALL NOT BE INSTALLED WITHIN 4 FEET
(MEASURED HORIZONTALLY) OF GAS REGULATORS AND
RELIEF VALVES.

5. SOLAR PV EQUIPMENT WITH A READOUT DISPLAY WILL

TYPICALLY BE MOUNTED WITH THE DISPLAY AT EYE LEVEL,
APPROXIMATELY 63-65 INCHES. OTHER EQUIPMENT WILL BE
MOUNTED A MINIMUM OF 18 INCHES FROM GRADE/GROUND
UNLESS OTHERWISE SPECIFIED BY CEC CODE.

GRADE
Scale: 1/2" = 1'-0"
EQUIPMENT ELEVATIONS - INVERTERS AT PV ARRAY BA4
GRADE
Scale: 1" = 1'-0"
EQUIPMENT ELEVATIONS - MONITORING RACKC1
GRADE

ALSOENERGY DAS ENCLOSURE

FRONT REAR

CHINT PLC ENCLOSURE

ALSOENERGY DAS ENCLOSURE
(BEHIND)
5kVA AUX. TRANSFORMER
(BEHIND)
5kVA AUX.

TRANSFORMER
AUX. POWER PANELBOARD
NEMA 3R 120V

SERVICE OUTLET

CHINT PLC ENCLOSURE
(BEHIND)
(1) 1" PVC40 TO INV.02
(1) 1" PVC40 TO INV.03
(1) 1" PVC40 TO PV METER
(1) 3/4" PVC40 TO WEATHER STATION
(1) 3/4" EMT TO AUX.

POWER PANELBOARD
(1) 3/4" EMT
(DATA)
(1) 3/4" PVC40
TO SWGR.02
(1) 3/4" EMT
(1) 3/4" EMT
(AUX. POWER)
(1) 3/4" EMT TO

ALSOENERGY DAS

ENCLOSURE
(1) 3/4" PVC40
TO SWGR.02
INV.01 INV.02 ACC.01 INV.04 INV.03 ACC.02INV.05
(2) 2" PVC40 (DC PV POWER)
(1) 1" PVC40 (DC PV POWER)
(2) 2" PVC40 (DC PV POWER)
(1) 1-1/4" PVC40 (DC PV POWER)
(1) 1" PVC40 TO DAS (DATA)
(1) 1" EMT
(DATA)
(1) 3" EMT
(AC PV POWER)
(1) 3" EMT
(AC PV POWER)
(2) 3" PVC40 TO ACRC.01
(AC PV POWER)
(2) 2" PVC40 (DC PV POWER)
(1) 1" PVC40 (DC PV POWER)
(2) 2" PVC40 (DC PV POWER)
(1) 1-1/2" PVC40 (DC PV POWER)
(2) 2" PVC40 (DC PV POWER)
(1) 1" PVC40 (DC PV POWER)
(1) 1" PVC40 TO DAS (DATA)
(1) 1" EMT
(DATA)
(1) 3" EMT
(AC PV POWER)
(1) 3" EMT
(AC PV POWER)
(1) 3" EMT
(AC PV POWER)
(2) 3" PVC40 TO ACRC.01
(AC PV POWER)
(1) 1" PVC40 TO GELI EMS
Scale: 3/4" = 1'-0"
EQUIPMENT ELEVATIONS - PV SWITCHGEAR (SWGR.02)C4
GRADE
SECTION 1 -

MAIN CIRCUIT

BREAKER
(MCB.02)
SECTION 2 -
ACRC
7'-6"
7'

PROFESSIO
NA
L

ENGINEER
E19765
Front View Right View
STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024
SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET
KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765

EQUIPMENT

ELEVATIONS
WI201.2
Scale: 3/8" = 1'-0"
EQUIPMENT ELEVATIONS - BESSA1

1. DISPLAY A PERMANENT PLAQUE OR DIRECTORY PROVIDING

THE LOCATION OF THE UTILITY SERVICE DISCONNECTING

MEANS AND THE PHOTOVOLTAIC DISCONNECTING MEANS IF
NOT LOCATED AT THE SAME LOCATION.

2. ALL DIMENSIONS ARE APPROXIMATE AND MUST BE FIELD
VERIFIED.

3. ALL SOLAR PV EQUIPMENT SHALL HAVE A MINIMUM WORKING
CLEARANCE OF 36 INCHES IN FRONT AND 6 INCHES ON EACH
SIDE.

4. METERS SHALL NOT BE INSTALLED WITHIN 4 FEET
(MEASURED HORIZONTALLY) OF GAS REGULATORS AND
RELIEF VALVES.

5. SOLAR PV EQUIPMENT WITH A READOUT DISPLAY WILL

TYPICALLY BE MOUNTED WITH THE DISPLAY AT EYE LEVEL,
APPROXIMATELY 63-65 INCHES. OTHER EQUIPMENT WILL BE
MOUNTED A MINIMUM OF 18 INCHES FROM GRADE/GROUND
UNLESS OTHERWISE SPECIFIED BY CEC CODE.

GENERAL SHEET NOTES
GRADE
Scale: 3/4" = 1'-0"
EQUIPMENT ELEVATIONS - PV & BESS SWITCHGEAR (SWGR.01)C1 GRADE
7'-6"
13'-6"
SECTION 1 -

MAIN BREAKER
SECTION 2 -

BESS SERVICE

BREAKERS
SECTION 3 -

PV METER &

DISCONNECT
SECTION 4 -

PV SERVICE
FUSED

DISCONNECT
9'-1 1/2"
28'-10 1/2" 5'-4 1/2"
Scale: 1" = 1'-0"
EQUIPMENT ELEVATIONS - SITE CONTROLLER RACKA5
GRADE
AUX. POWER PANELBOARD
(BEHIND)

TESLA SITE CONTROLLER

GELI EMS
(1) 1-1/4" PVC40
AUX. POWER PANELBOARD
TO SWGR.01
(1) 1" EMT
(EMS POWER)
(1) 1" EMT
(DATA)
(1) 1" PVC40 TO PV METER
(1) 1" PVC40 TO BESS METER
(1) 1" PVC40 TO SITE METER
(1) 1" PVC40 TO BESS COMM. BOARD
(1) 1" EMT
(TSC POWER)
(1) 1" EMT TO

AE BESS ENCLOSURE

ALSOENERGY REMOTE ENCLOSURE FOR BESS
(BEHIND)
Scale: 1" = 1'-0"
EQUIPMENT ELEVATIONS - SITE CONTROLLER RACKC4
GRADE
AUX. POWER

PANELBOARD

TESLA SITE CONTROLLER
(BEHIND) GELI EMS (BEHIND)
(1) 1-1/4" PVC40
AUX. POWER PANELBOARD TO SWGR.01
(1) 1" EMT
(EMS POWER)
(1) 1" PVC40, EMS TO PV METER
(1) 1" PVC40, EMS TO BESS METER
(1) 1" PVC40, EMS TO SITE METER
(1) 1" PVC40, TSC TO
BESS COMM. BOARD
(1) 1" EMT
(TSC POWER)
(1) 1" EMT TO GELI EMS

ALSOENERGY REMOTE

ENCLOSURE FOR BESS
(1) 1" EMT
(AE POWER)
(1) 1" EMT
(AE POWER)

PROFESSIO
NA
L

ENGINEER
E19765
STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024
SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET
KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765

EQUIPMENT

ELEVATIONS
WI201.3

1. DISPLAY A PERMANENT PLAQUE OR DIRECTORY PROVIDING

THE LOCATION OF THE UTILITY SERVICE DISCONNECTING

MEANS AND THE PHOTOVOLTAIC DISCONNECTING MEANS IF
NOT LOCATED AT THE SAME LOCATION.

2. ALL DIMENSIONS ARE APPROXIMATE AND MUST BE FIELD
VERIFIED.

3. ALL SOLAR PV EQUIPMENT SHALL HAVE A MINIMUM WORKING
CLEARANCE OF 36 INCHES IN FRONT AND 6 INCHES ON EACH
SIDE.

4. METERS SHALL NOT BE INSTALLED WITHIN 4 FEET
(MEASURED HORIZONTALLY) OF GAS REGULATORS AND
RELIEF VALVES.

5. SOLAR PV EQUIPMENT WITH A READOUT DISPLAY WILL

TYPICALLY BE MOUNTED WITH THE DISPLAY AT EYE LEVEL,
APPROXIMATELY 63-65 INCHES. OTHER EQUIPMENT WILL BE
MOUNTED A MINIMUM OF 18 INCHES FROM GRADE/GROUND
UNLESS OTHERWISE SPECIFIED BY CEC CODE.

GENERAL SHEET NOTES
Scale: 3/4" = 1'-0"
EQUIPMENT ELEVATIONS - UTILITY DISCONNECT (ACD.01) SIDE VIEWA3 GRADE
Scale: 3/4" = 1'-0"
EQUIPMENT ELEVATIONS - UTILITY DISCONNECT (ACD.01) FRONT VIEWA1 GRADE
7'-6"
6'-9"

EXISTING ELECTRICAL SERVICE BUILDING

PULL SECTIONUTILITY

DISCONNECT
(ACD.01)
(8) 4" RMC TO PV

INTERCONNECTION

SECTION IN MAIN SERVICE

SWITCHBOARD (BUILDING

INTERIOR)
(1) 3/4" EMT (DATA)

TO MAIN BUILDING

SWITCHBOARD
(BUILDING

INTERIOR)

UTILITY

DISCONNECT
(ACD.01)
(1) 3/4" EMT/PVC40
(DATA) FROM GELI

EMS TO OVERALL

SITE METER
PVC40 TO EMT

TRANSITION

WALL-MOUNTED, WELDED

FRAME, STEEL CONDUIT

SUPPORT BRACKET

NEW OVERALL SITE METER
(SEL-735) FOR BESS CONTROLLER
IN NEMA 3R ENCLOSURE,

WALL MOUNTED
(8) 4" RMC TO PV

INTERCONNECTION

SECTION IN MAIN SERVICE

SWITCHBOARD (BUILDING

INTERIOR)
(1) 3/4" EMT (DATA) TO MAIN

BUILDING SWITCHBOARD
(BUILDING INTERIOR)
(1) 1" EMT/PVC40 (DATA)

FROM GELI EMS TO

OVERALL OUTPUT
METER

WALL-MOUNTED, WELDED

FRAME, STEEL CONDUIT
SUPPORT BRACKET (TYP.)

EXISTING ELECTRICAL SERVICE BUILDING

EXISTING BUS DUCT FROM UTILITY TRANSFORMER

TO MAIN SERVICE SWITCHBOARD,

FOR REFERENCE ONLY, NOT IN SCOPE

EXISTING PULL BOX AT BUILDING
INTERIOR WALL; CONDUCTORS TO

LAND THERE AND TRANSITION TO

INTERCONNECTION AT MAIN SERVICE

SWITCHBOARD
NEW 36" X 36" X 12" NEMA 3R PULL BOX

FOR CONDUIT TRANSITION TO

BUILDING INTERIOR
NEW 36" X 36" X 12" NEMA 3R PULL BOX

FOR CONDUIT TRANSITION TO

BUILDING INTERIOR

INSULATED CONDUCTOR TRANSITION

TO PULL BOX IN BUILDING INTERIOR

COORDINATE SUPPORTS

FOR PULL BOX WITH

EXISTING WALL OPENING

NEW OVERALL OUTPUT
METER (SEL-735) IN
NEMA 3R ENCLOSURE,

WALL MOUNTED
(1) 1" EMT (DATA) FROM

OVERALL SITE METER TO

OUTPUT METER
(1) 3/4" EMT/PVC40
(DATA) TO ACD.01
(1) 3/4" EMT/PVC40
(DATA) FROM

OVERALL OUTPUT
METER TO ACD.01

NEW OVERALL OUTPUT
METER (SEL-735) IN
NEMA 3R ENCLOSURE,

WALL MOUNTED

PROFESSIO
NA
L

ENGINEER
E19765
INV
-01-
01 INV
-01-
02 INV
-01-
03 INV
-01-
04 INV
-02-
09 INV
-02-
20 INV
-01-
05 INV
-01-
06 INV
-01-
07 INV
-01-
08 INV
-01-
09 INV
-01-
10 INV
-01-
11 INV
-01-
12 INV
-01-
13 INV
-01-
14 INV
-01-
15 INV
-01-
16 INV
-01-
17 INV
-01-
18 INV
-01-
19 INV
-01-
20 INV
-01-
21 INV
-01-
22 INV-01-
23 INV-01-
24 INV-02-
01 INV-02-
02 INV-02-
03 INV-02-
04 INV
-02-
05 INV
-02-
06 INV
-02-
07 INV
-02-
08 INV
-02-
10 INV
-02-
11 INV
-02-
12 INV
-02-
13 INV
-02-
14 INV
-02-
15 INV
-02-
16 INV
-02-
17 INV
-02-
18 INV
-02-
19 INV
-02-
21 INV
-02-
22 INV
-02-
23 INV
-02-
24 INV
-03-
01 INV
-03-
02 INV
-03-
03 INV
-03-
04 INV
-03-
05 INV
-03-
06 INV
-03-
07 INV
-03-
08 INV
-03-
09 INV
-03-
10 INV
-03-
11 INV
-03-
12 INV
-03-
13 INV
-03-
14 INV
-03-
16 INV
-03-
17 INV
-03-
18 INV
-03-
19 INV
-03-
21 INV
-03-
22 INV
-03-
23 INV
-03-
24 INV
-04-
01 INV
-04-
02 INV
-04-
03 INV
-04-
04 INV
-04-
05 INV
-04-
06 INV
-04-
07 INV
-04-
08 INV
-04-
09 INV
-04-
10 INV
-04-
11 INV
-04-
12 INV
-04-
13 INV
-04-
14 INV
-04-
15 INV
-04-
16 INV
-04-
17 INV
-04-
18 INV
-04-
20 INV
-04-
21 INV
-05-
05 INV
-04-
19 INV
-03-
15 INV
-03-
20 INV
-04-
22 INV
-04-
23 INV
-04-
24 INV
-05-
01 INV
-05-
02 INV
-05-
03 INV
-05-
04 INV
-05-
06 INV
-05-
07 INV
-05-
08 INV
-05-
09 INV
-05-
11 INV
-05-
12 INV
-05-
13 INV
-05-
14 INV
-05-
15 INV
-05-
16 INV
-05-
17 INV
-05-
18 INV
-05-
22 INV
-05-
23 INV
-05-
19 INV
-05-
20 INV
-05-
24 INV
-05-
21 INV
-05-
10 INV-XX-
XX

INVERTER NUMBER

STRING NUMBER

MODULES WITHIN STRING

END OF STRING
STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024

SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET

KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765

GENERAL SHEET NOTES

1. ALL DIMENSIONS ARE APPROXIMATE AND MUST BE FIELD
VERIFIED.

2. SHADING ANALYSIS IS BASED UPON DECEMBER 21ST AS THE

LONGEST SHADOW DAY OF THE YEAR CALCULATED
AROUND SOLAR NOON. TYPICAL SOLAR HOURS ARE FROM
9AM-3PM, MINIMUM IS 10AM-2PM.

3. SHADING FROM TREES, BUSHES AND OTHER VEGETATION IS
ESTIMATED BY THEIR CURRENT SIZE. TO AVOID SHADING

THE PV ARRAYS, VEGETATION SHALL BE MONITORED AT
REGULAR INTERVALS AND TRIMMED AS NECESSARY.

4. MINIMUM BENDING RADIUS OF PHOTOVOLTAIC MODULE

LEADS SHALL CONFORM WITH MINIMUM BENDING RADIUS

SET FORTH BY THE MODULE MANUFACTURER OR ARTICLE
338.24, WHICHEVER IS MORE STRINGENT.

MODULE

STRINGING PLAN
WP101.1
Scale: 1/32" = 1'-0"
MODULE STRINGING PLANA1
PLAN
NORTH
LEGEND
SHEET WP101.2 SHEET WP101.3
SHEET WP101.4

PROFESSIO
NA

L ENGINEER
E19765

INV-XX-
XX

INVERTER NUMBER

STRING NUMBER

MODULES WITHIN STRING

END OF STRING
INV
-01-
01 INV
-01-
02 INV
-01-
03 INV
-01-
04 INV
-02-
09 INV
-02-
20 INV
-01-
05 INV
-01-
06 INV
-01-
07 INV
-01-
08 INV
-01-
09 INV
-01-
10 INV
-01-
11 INV
-01-
12 INV
-01-
13 INV
-01-
14 INV
-01-
15 INV
-01-
16 INV
-01-
17 INV
-01-
18 INV
-01-
19 INV
-01-
20 INV
-01-
21 INV
-01-
22 INV
-01-
23 INV
-01-
24 INV
-02-
01 INV
-02-
02 INV
-02-
03 INV
-02-
04 INV
-02-
05 INV
-02-
06 INV
-02-
07 INV
-02-
08 INV
-02-
10 INV
-02-
11 INV
-02-
12 INV
-02-
13 INV
-02-
14 INV
-02-
15 INV
-02-
16 INV
-02-
17 INV
-02-
18 INV
-02-
19 INV
-02-
21 INV
-02-
22 INV
-02-
23 INV
-02-
24 INV
-04-
03 INV
-04-
04 STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024

SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET

KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765

GENERAL SHEET NOTES

1. ALL DIMENSIONS ARE APPROXIMATE AND MUST BE FIELD
VERIFIED.

2. SHADING ANALYSIS IS BASED UPON DECEMBER 21ST AS THE

LONGEST SHADOW DAY OF THE YEAR CALCULATED
AROUND SOLAR NOON. TYPICAL SOLAR HOURS ARE FROM
9AM-3PM, MINIMUM IS 10AM-2PM.

3. SHADING FROM TREES, BUSHES AND OTHER VEGETATION IS
ESTIMATED BY THEIR CURRENT SIZE. TO AVOID SHADING

THE PV ARRAYS, VEGETATION SHALL BE MONITORED AT
REGULAR INTERVALS AND TRIMMED AS NECESSARY.

4. MINIMUM BENDING RADIUS OF PHOTOVOLTAIC MODULE

LEADS SHALL CONFORM WITH MINIMUM BENDING RADIUS

SET FORTH BY THE MODULE MANUFACTURER OR ARTICLE
338.24, WHICHEVER IS MORE STRINGENT.

MODULE

STRINGING PLAN
WP101.2
LEGEND
Scale: 1/16" = 1'-0"
MODULE STRINGING PLANA1
PLAN
NORTH
SEE SHEET WP101.3

PROFESSIO
NA

L ENGINEER
E19765

INV-XX-
XX

INVERTER NUMBER

STRING NUMBER

MODULES WITHIN STRING

END OF STRING
INV
-01-
05 INV
-01-
06 INV
-01-
13 INV
-01-
14 INV
-01-
21 INV
-01-
22 INV
-03-
01 INV
-03-
02 INV
-03-
03 INV
-03-
04 INV
-03-
05 INV
-03-
06 INV
-03-
07 INV
-03-
08 INV
-03-
09 INV
-03-
10 INV
-03-11
INV
-03-12
INV
-03-13
INV
-03-14
INV
-03-
16 INV
-03-
17 INV
-03-
18 INV
-03-
19 INV-03-
21 INV-03-
22 INV-03-
23 INV-03-
24 INV-04-
01 INV-04-
02 INV
-03-15
INV
-03-
20 STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024

SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET

KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765

GENERAL SHEET NOTES

1. ALL DIMENSIONS ARE APPROXIMATE AND MUST BE FIELD
VERIFIED.

2. SHADING ANALYSIS IS BASED UPON DECEMBER 21ST AS THE

LONGEST SHADOW DAY OF THE YEAR CALCULATED
AROUND SOLAR NOON. TYPICAL SOLAR HOURS ARE FROM
9AM-3PM, MINIMUM IS 10AM-2PM.

3. SHADING FROM TREES, BUSHES AND OTHER VEGETATION IS
ESTIMATED BY THEIR CURRENT SIZE. TO AVOID SHADING

THE PV ARRAYS, VEGETATION SHALL BE MONITORED AT
REGULAR INTERVALS AND TRIMMED AS NECESSARY.

4. MINIMUM BENDING RADIUS OF PHOTOVOLTAIC MODULE

LEADS SHALL CONFORM WITH MINIMUM BENDING RADIUS

SET FORTH BY THE MODULE MANUFACTURER OR ARTICLE
338.24, WHICHEVER IS MORE STRINGENT.

MODULE

STRINGING PLAN
WP101.3
LEGEND
Scale: 1/16" = 1'-0"
MODULE STRINGING PLANA1
PLAN
NORTH
SEE SHEET WP101.2
SEE SHEET WP101.4

PROFESSIO
NA

L ENGINEER
E19765

INV-XX-
XX

INVERTER NUMBER

STRING NUMBER

MODULES WITHIN STRING

END OF STRING
INV
-03-
21 INV
-03-
22 INV
-03-
23 INV
-03-
24 INV
-04-
01 INV
-04-
02 INV
-04-
03 INV
-04-
04 INV
-04-
05 INV
-04-
06 INV
-04-
07 INV
-04-
08 INV
-04-
09 INV
-04-
10 INV
-04-
11 INV
-04-
12 INV
-04-
13 INV
-04-
14 INV
-04-
15 INV
-04-
16 INV
-04-
17 INV
-04-
18 INV
-04-
20 INV
-04-
21 INV
-05-
05 INV
-04-
19 INV
-04-
22 INV
-04-
23 INV
-04-
24 INV
-05-
01 INV
-05-
02 INV
-05-
03 INV
-05-
04 INV
-05-
06 INV
-05-
07 INV
-05-
08 INV
-05-
09 INV
-05-
11 INV
-05-
12 INV
-05-
13 INV
-05-
14 INV
-05-
15 INV
-05-
16 INV
-05-
17 INV
-05-
18 INV
-05-
22 INV
-05-
23 INV
-05-
19 INV
-05-
20 INV
-05-
24 INV
-05-
21 INV
-05-
10 STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024

SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET

KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765

GENERAL SHEET NOTES

1. ALL DIMENSIONS ARE APPROXIMATE AND MUST BE FIELD
VERIFIED.

2. SHADING ANALYSIS IS BASED UPON DECEMBER 21ST AS THE

LONGEST SHADOW DAY OF THE YEAR CALCULATED
AROUND SOLAR NOON. TYPICAL SOLAR HOURS ARE FROM
9AM-3PM, MINIMUM IS 10AM-2PM.

3. SHADING FROM TREES, BUSHES AND OTHER VEGETATION IS
ESTIMATED BY THEIR CURRENT SIZE. TO AVOID SHADING

THE PV ARRAYS, VEGETATION SHALL BE MONITORED AT
REGULAR INTERVALS AND TRIMMED AS NECESSARY.

4. MINIMUM BENDING RADIUS OF PHOTOVOLTAIC MODULE

LEADS SHALL CONFORM WITH MINIMUM BENDING RADIUS

SET FORTH BY THE MODULE MANUFACTURER OR ARTICLE
338.24, WHICHEVER IS MORE STRINGENT.

MODULE

STRINGING PLAN
WP101.4
LEGEND
Scale: 1/16" = 1'-0"
MODULE STRINGING PLANA1
PLAN
NORTH
SEE SHEET WP101.4

PROFESSIO
NA

L ENGINEER
E19765

CONDUIT SUPPORT

AS REQUIRED BY CEC

STEEL POST, BEAM,

OR WALL

PLASTIC COUPLING

GRADE / TOP OF SLAB
PER
CEC
90° PVC40

CONDUIT
BEND
MIN. 6"
MAX. 12"

PLASTIC COUPLING

ENGINEERED BACKFILL
AT 95% COMPACTION
GRADE
8" MIN.
3/4" X 10' COPPER CLAD

GROUND ROD

ALL COVERED

CONNECTIONS SHALL BE

CAD WELD OR EQUAL

GROUND RING OR

BONDING

CONDUCTOR

WEATHERHEAD
1-5/8" UNISTRUT
(6" MIN LENGTH)

UNISTRUT STRAP

SOLAR MODULE
STRING

CONDUCTORS
GRADE

REPRESENTATIVE

CONDUIT
NOTE:
2022 CEC 210.5(C)(2) REQUIRES

IDENTIFICATION OF POSITIVE

AND NEGATIVE CONDUCTORS
IN DC SYSTEMS.

CIRCUITS MUST TRAVEL
TOGETHER IN SAME CONDUIT.

SPLIT LOOM

PROTECTIVE

HOUSING

DRIP LOOP

CONDUIT

GROUNDING CLAMP
#6 BARE COPPER

GROUNDING CONDUCTOR

CROSS SECTION LONGITUDINAL SECTION
NOTES:

1. CONTRACTOR SHALL SIZE PER CEC REQUIREMENTS.

2. ADJUST DEPTH PER DEPTH OF CONDUITS AND DUCTBANKS.

3. FOR CABLE PULLING ONLY, SPLICES NOT PERMITTED.

4. LID AND HANDHOLE SHALL BE SECURED WITH LOCKABLE BOLTS.

5. HANDHOLE MUST BE TRAFFIC RATED AND WITHSTAND WET LOCATION CONDITIONS.

CONCRETE RING

AROUND BOX

CONDUITS
3/8" PEA ROCK

FINISHED
GRADE
COVER

ENGINEERED BACKFILL
AT 95% COMPACTION
20" MIN.

AC BREAKER BOX
TRANS-
FORMER

INVERTER
GENERAL NOTES:

1. REFER TO BONDING INSTRUCTIONS SPECIFIC TO TERRASMART FOR RACKING GROUNDING DETAILS.

2. REFER TO WIRE TABLES ON SHEET WP601.3 FOR EGC SIZES.

3. MODULES, WEEBS, AND RAIL STRUCTURE IS UL2703 LISTED AS AN EGC.

GRADE
G
G
G G
AC

AGGREGATION
PANEL
G
G G
G
G

INVERTER
G

TO ARRAY
G

INVERTER
G

TO ARRAY

TO AC BREAKER BOX
G G

PV & BESS

SWITCHGEAR
G G

UTILITY AC

DISCONNECT
G G

CUSTOMER

SWITCHGEAR
G G
G

BESS UNIT
G
G

MODULES BONDED TO RAILS

THAT ARE BONDED TO COLUMNS
G

CADWELD OR GROUND

LUG TO COLUMN

RACKING FOUNDATION TO BE COLUMNS

OR GROUND SCREWS AT A DEPTH

DETERMINED BY STRUCTURAL ENGINEER

REPRESENTATIVE

CONDUCTORS

CONTINUOUS GROUND

STRIP INSULATION AT LUG

ENCLOSURE WALL REPRESENTATIVE

BUSHING

INTERMEDIATE

METAL CONDUIT
12"
MARKER
DEPTH
MIN.

DEPTH

UNDERGROUND

MARKER TAPE

SEE ELECTRICAL WIRING
PLAN FOR EXACT NO. OF
CONDUITS AND WIRE.

CONDUIT, OAE IS

REQUIRED UNDERGROUND

REPLACE CONCRETE AND
GRAVEL TO MATCH EXISTING.

IF GRASS IS PRESENT, RESTORE
TO PREVIOUS CONDITION.

GRADE
18" BENEATH NON-TRAFFIC AREAS
24" BENEATH PARKING LOTS AND ROADWAYS

ENGINEERED BACKFILL
AT 95% COMPACTION
STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024

SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET

KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765

ELECTRICAL

DETAILS
WP501
Scale: NTS
ELECTRICAL DETAILS - CONDUIT RISERA1 Scale: NTS
ELECTRICAL DETAILS - GROUND ROD INSTALLATIONA3 Scale: NTS ELECTRICAL DETAILS - STRING WIRING CONDUIT ENTRYA5
Scale: NTS
ELECTRICAL DETAILS - HAND HOLEB1
Scale: NTS
ELECTRICAL DETAILS - METALLIC CONDUIT GROUNDD1
Scale: NTS
ELECTRICAL DETAILS -GROUNDING SINGLE LINEB3
Scale: NTS
ELECTRICAL DETAILS - TRENCHING DETAILD3 Scale: NTS
ELECTRICAL DETAILS - XXD5

PROFESSIO
NA

L ENGINEER
E19765
992.5A
#4/0 Cu BOND TO

GROUND RING (TYP)
4 PV SWITCHGEAR (SWGR.02)
800V, 1400A BUS (OAE),
NEMA 3R, 3ɸ, 3W , 65 KAIC
PER CEC 705.12(B)(3)(3)

SERVICE ENTRY RATED

PAD MOUNTED AT ARRAY
7 500A/3P
SECTION 2 - ACRC
(1) 750A, 3P BREAKER
(1) 500A, 3P BREAKER
(2) 20A, 3P BREAKERS
(1) 20A, 2P BREAKER
K
J
20A/3P
SURGE

ARRESTOR

EXOTHERMIC BOND (TYP)
(1) 3/4" X 10' GROUNDING

ELECTRODES (TYP OF ALL

GROUND RODS)

GROUND ROD

GROUND ROD
SECTION 1 - MAIN CIRCUIT
BREAKER MCB.02
GFP PER CEC 215.10,

ARC ENERGY REDUCTION
PER CEC 240.87
750A/3P
CHINT SCA275KTL-DO/US-800-36
800V 3PH-3W-198.5A AC OUTPUT,

DC & AC SURGE ARRESTORS,

AFCI - RACK MOUNTED AT ARRAY
1 3
DC
AC
25A(TYP)

GFDI COMM
INV.01
198.5A
1 3 9 10 11
A
12 25
# OF MODULES IN SERIES

18.8A
(4) ADDITIONAL

INVERTERS
IDENTICAL TO INV.01
B 12

TO PV XFMR,
SEE SHEET WP601.3
24 STRINGS

PER INVERTER
AC COMBINER (ACC.01)
CPS DBA03-800V/US
800V, 1000A BUS (OAE)
NEMA 3R, 3W,
(2) 250A 100% RATED BREAKERS
CEC 705.12(B)(3)(3)

RACK MOUNTED AT ARRAY
397.0A G
12 198.5AINV.02
C
12 AC COMBINER (ACC.02)
CPS DBA03-800V/US
800V, 1000A BUS (OAE)
NEMA 3R, 3W,
(3) 250A 100% RATED BREAKERS
CEC 705.12(B)(3)(3)

RACK MOUNTED AT ARRAY
595.5A H
12 198.5AINV.04
E
12 198.5AINV.05
F
12 12
13 198.5AINV.03
D
24DC/120V

GSM CELL
MODEM
(1) SHIELDED CAT6,
APPROX 10' IN 3/4" EMT
800V 120V
5kVA AUXILIARY

TRANSFORMER

RACK MOUNTED

AUXILIARY

POWER PANEL
20A/1P
(1H, 1N, 1G) #10 THWN-2
IN 3/4" EMT, APPROX. 10'
(3H, 1G) #10 THWN-2
IN 3/4" PVC40, APPROX. 10'
(1H, 1N, 1G) #10 THWN-2
IN 3/4" EMT, APPROX. 10'
20A/1P
(1H, 1N, 1G) #10 THWN-2
IN 3/4" EMT, APPROX. 10'
NEMA 3R 120V

SERVICE OUTLET
(2H, 1G)
#14 THWN-2
IN 3/4" PVC40,
APPROX. 10'
20A/3P
20A/2P
24DC/120V
800V/120V

CPS-AC-PLC
FLEX

GATEWAY

CHINT PLC

ENCLOSURE
01 (PLC.01)
4 7
4 7
RS-485 TWISTED PAIR/24V,
(2) BELDEN 3106A OAE,
APPROX 65' IN 3/4" PVC40
RS-485 IN 1" EMT/PVC40 ~315'TO INV.01 - INV.02
RS-485 IN 1" EMT/PVC40 ~80'TO INV.03 - INV.05
1600AF
1350AT
3P
DATA
LOGGER

ALSO ENERGY

MONITORING BOX
(COMM.01)
RS-485 IN 1" EMT/PVC40 ~315'TO INV.01 - INV.02
RS-485 IN 1" EMT/PVC40 ~80'TO INV.03 - INV.05

PHOTOVOLTAIC ARRAY
(3000) QCELLS Q.PEAK DUO XL-G11S.3/BFG 595, 595W MODULES, OAE (120) STRINGS OF (25) MODULES
(5) CHINT CPS SCH275KTL-DO/US-800-36 INVERTERS - 250KW AC SELECTED RACKING SHALL BE UL 2703 LISTED AS AN EGC
BARE 6 AWG EGC ATTACHED TO RAIL ENDS WITH WEEB LUGS
1500V PV WIRE FOR ALL SOURCE WIRING

BATTERY ENERGY STORAGE SYSTEM
(1) TESLA MEGAPACK 2 XL 4HR (448.8kW/1795.2kWh)
FROM SEL-735 PV METER
SEE SHEET WP601.3
RS-485 TWISTED PAIR
IN 1" PVC40 ~725' (DATA)

WEATHER

STATION
(MOUNTED AT

ARRAY B)
IGHI
IBOM
TAMB.

VWIND
POA SENSOR (Si-RS485TC-2T-v-MB)
AND T-BOM SENSOR (Tmodul-Si) TO

MATCH THE TILT AND ORIENTATION

OF THE MODULES
STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024

SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET

KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765

ELECTRICAL SLD -
PV
WP601.1
SCALE: NTS
ELECTRICAL SLD - PVA1

GENERAL SHEET NOTES

SHEET KEYNOTES

1. EQUIPMENT SHALL BE INSTALLED AND LABELED IN

ACCORDANCE WITH THE CEC AND ALL APPLICABLE

REQUIREMENTS OF THE SERVING UTILITY COMPANY AND
LOCAL AUTHORITY HAVING JURISDICTION (AHJ).

2. DISCONNECTS MUST COMPLY WITH CEC 690.15 AND PROVIDE
WARNING SIGN PER CEC 690.13. FUSED DISCONNECT SWITCH
TO HAVE GROUND FAULT PROTECTION PER CEC 230.95 AND
ARC ENERGY REDUCTION PER CEC 240.67 INCLUDING
PERFORMANCE TESTING BY QUALIFIED PERSONALE.

3. LISTING AGENCY NAMES AND NUMBERS TO BE INDICATED ON
POWER INVERTER AND SOLAR MODULES PER CEC 110.3(B).

4. LABELED "PHOTOVOLTAIC SYSTEM AC COMBINER."

5. UTILITY METER LABELED "PHOTOVOLTAIC SYSTEM
MONITOR.” CT COMPARTMENT PER EUSERC 322, 330. METER
DOOR PER EUSERC 333. METER SOCKET IS 15J.

6. LABELED “PHOTOVOLTAIC SYSTEM UTILITY DISCONNECT”

SWITCH TO BE VISUAL OPEN AND ACCESSIBLE AND
CONFORM TO CEC 705.22.

7. LABELED “WARNING: THIS PANEL SUPPLIED BY MULTIPLE
SOURCES OF POWER: 1. UTILITY POWER, 2. PHOTOVOLTAIC
SYSTEM - DISCONNECT ALL SOURCES BEFORE SERVICING.”

8. POINT OF INTERCONNECTION SHALL BE IN ACCORDANCE
WITH CEC 705.11. SOLAR-READY BREAKER TO HAVE GROUND
FAULT PROTECTION PER CEC 215.10 AND ARC ENERGY
REDUCTION PER CEC 240.87.

9. PROVIDE IDENTIFICATION ALONG WITH POSITIVE & NEGATIVE CONDUCTORS PER CEC 210.5(C)(2).

10. MINIMUM BENDING RADIUS OF PHOTOVOLTAIC MODULE

LEADS SHALL CONFORM WITH MINIMUM BENDING RADIUS

SET FORTH BY THE MODULE MANUFACTURER OR ARTICLE
338.24, WHICHEVER IS MORE STRINGENT.

11. MATING CONNECTORS FOR PV SOURCE CIRCUITS, PV

JUMPER CABLES, AND MODULE LEVEL POWER ELECTRONICS

TO BE LISTED AND IDENTIFIED FOR INTERMATABILITY, AS
DESCRIBED IN MANUFACTURER'S INSTRUCTIONS. MATING

CONNECTORS THAT ARE NOT LISTED ARE NOT TO BE
UTILIZED FOR PROJECT.

12. AC POWER CONDUITS TO CONVEY (3) CURRENT CARRYING
CONDUCTORS AND AN EGC. NO NEUTRAL REQUIRED.

13. ALL INVERTERS ARE TO HAVE THE MAX 250kW AC OUTPUT
OPTION SELECTED. REFER TO INVERTER DATA SHEET ON
SHEET WK801.

1. CONDUIT ABOVE GRADE SHALL BE EMT. ALL CONDUIT BELOW
GRADE SHALL BE PVC OR HDPE WITH RMC RISER. USE
SCHEDULE 40 FOR BELOW GRADE CONDUIT RUN UNDER
GRASSY AREAS.

2. ALL COPPER (CU) CONDUCTORS IN CONDUIT SHALL BE
THWN-2 OR XLPE. ALL EXPOSED CONDUCTORS SHALL BE
PVWIRE. ALL ALUMINUM (AL) CONDUCTORS IN CONDUIT
SHALL BE XHHW-2, OR XLPE.

3. ALUMINUM CONDUCTORS SHALL BE BRUSHED AND TREATED
WITH ANTIOXIDANT COMPOUND AT TERMINAL POINTS.

4. TORQUE: ALL CONDUCTORS LANDING IN SCREW

CONNECTIONS MUST BE PROPERLY TIGHTENED TO THE
MANUFACTURER'S TORQUE REQUIREMENTS. ALL BOLTED

CONDUCTOR TERMINATIONS MUST BE TORQUED TO THEIR
RATED VALUE. IT IS THE SUBCONTRACTOR'S

RESPONSIBILITY TO ENSURE ALL CONDUCTORS WITH

TORQUE REQUIREMENTS HAVE BEEN MARKED WITH A PAINT

PEN OR PERMANENT MARKER

AT THE TIME THAT THE
TORQUE TEST WAS DONE.

5. SOLAR ENERGY PRODUCTION MONITORING SHALL BE
INSTALLED AT PV & BESS SWITCHGEAR.

6. IMPACT DRIVERS ARE NOT APPROVED FOR USE ON
INVERTERS OR WIRE BOXES.

7. THE BESS WILL BE CONFIGURED TO ENSURE IT IS 100%

CHARGED FROM THE SOLAR PV SYSTEM WITH NO CHARGING
FROM THE UTILITY GRID. THIS WILL BE ACCOMPLISHED WITH

THE GELI ENERGY MANAGEMENT SYSTEM AND THE TESLA
SITE CONTROLLER SERVING AS A POWER CONTROL SYSTEM.

PROFESSIO
NA

L ENGINEER
E19765

BATTERY
MODULE

THERMAL

CABINET

INTERFACE
BAY
DC
AC
1600A/3P
DC
AC
DC
AC
DC
AC
COMM

BATTERY
MODULE

BATTERY
MODULE
DC
AC
DC
AC
DC
AC
DC
AC
M

TO TESLA CONTROLLER,
DATA AND 24VDC BACKUP
POWER ON WP601.4
EXOTHERMIC BOND (TYP)3/4" X 10' GROUNDING

ELECTRODES (TYP)

GROUND ROD

GROUND ROD
601.4A
TO SWGR.01

SEE DETAIL ON
WP601.3
LVA
TESLA MEGAPACK 2 XL (5.4.6.A/AB-448.8-1795.2)
480V, 448.8kW/1795.2kWh,
693kVA RATED, NEMA 3R

PAD MOUNTED AT EQUIPMENT YARD
STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024

SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET

KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765

ELECTRICAL SLD -
BESS
WP601.2
SCALE: NTS
ELECTRICAL SLD - BESSA1

GENERAL SHEET NOTES

SHEET KEYNOTES

1. EQUIPMENT SHALL BE INSTALLED AND LABELED IN

ACCORDANCE WITH THE CEC AND ALL APPLICABLE

REQUIREMENTS OF THE SERVING UTILITY COMPANY AND
LOCAL AUTHORITY HAVING JURISDICTION (AHJ).

3. LISTING AGENCY NAMES AND NUMBERS TO BE INDICATED ON
POWER INVERTER AND SOLAR MODULES PER CEC 110.3(B).

4. LABELED "PHOTOVOLTAIC SYSTEM AC COMBINER."

5. UTILITY METER LABELED "PHOTOVOLTAIC SYSTEM
MONITOR.” CT COMPARTMENT PER EUSERC 322, 330. METER
DOOR PER EUSERC 333. METER SOCKET IS 15J.

6. LABELED “PHOTOVOLTAIC SYSTEM UTILITY DISCONNECT”

SWITCH TO BE VISUAL OPEN AND ACCESSIBLE AND
CONFORM TO CEC 705.22.

7. LABELED “WARNING: THIS PANEL SUPPLIED BY MULTIPLE
SOURCES OF POWER: 1. UTILITY POWER, 2. PHOTOVOLTAIC
SYSTEM - DISCONNECT ALL SOURCES BEFORE SERVICING.”

8. POINT OF INTERCONNECTION SHALL BE IN ACCORDANCE
WITH CEC 705.11. SOLAR-READY BREAKER TO HAVE GROUND
FAULT PROTECTION PER CEC 215.10 AND ARC ENERGY
REDUCTION PER CEC 240.87.

9. PROVIDE IDENTIFICATION ALONG WITH POSITIVE & NEGATIVE CONDUCTORS PER CEC 210.5(C)(2).

10. MINIMUM BENDING RADIUS OF PHOTOVOLTAIC MODULE

LEADS SHALL CONFORM WITH MINIMUM BENDING RADIUS

SET FORTH BY THE MODULE MANUFACTURER OR ARTICLE
338.24, WHICHEVER IS MORE STRINGENT.

11. MATING CONNECTORS FOR PV SOURCE CIRCUITS, PV

JUMPER CABLES, AND MODULE LEVEL POWER ELECTRONICS

TO BE LISTED AND IDENTIFIED FOR INTERMATABILITY, AS
DESCRIBED IN MANUFACTURER'S INSTRUCTIONS. MATING

CONNECTORS THAT ARE NOT LISTED ARE NOT TO BE
UTILIZED FOR PROJECT.

12. AC POWER CONDUITS TO CONVEY (3) CURRENT CARRYING
CONDUCTORS AND AN EGC. NO NEUTRAL REQUIRED.

13. ALL INVERTERS ARE TO HAVE THE MAX 250kW AC OUTPUT
OPTION SELECTED. REFER TO INVERTER DATA SHEET ON
SHEET WK801.

1. CONDUIT ABOVE GRADE SHALL BE EMT. ALL CONDUIT BELOW
GRADE SHALL BE PVC OR HDPE WITH RMC RISER. USE
SCHEDULE 40 FOR BELOW GRADE CONDUIT RUN UNDER
GRASSY AREAS.

2. ALL COPPER (CU) CONDUCTORS IN CONDUIT SHALL BE
THWN-2 OR XLPE. ALL EXPOSED CONDUCTORS SHALL BE
PVWIRE. ALL ALUMINUM (AL) CONDUCTORS IN CONDUIT
SHALL BE XHHW-2, OR XLPE.

3. ALUMINUM CONDUCTORS SHALL BE BRUSHED AND TREATED
WITH ANTIOXIDANT COMPOUND AT TERMINAL POINTS.

4. TORQUE: ALL CONDUCTORS LANDING IN SCREW

CONNECTIONS MUST BE PROPERLY TIGHTENED TO THE
MANUFACTURER'S TORQUE REQUIREMENTS. ALL BOLTED

CONDUCTOR TERMINATIONS MUST BE TORQUED TO THEIR
RATED VALUE. IT IS THE SUBCONTRACTOR'S

RESPONSIBILITY TO ENSURE ALL CONDUCTORS WITH

TORQUE REQUIREMENTS HAVE BEEN MARKED WITH A PAINT

PEN OR PERMANENT MARKER

AT THE TIME THAT THE
TORQUE TEST WAS DONE.

5. SOLAR ENERGY PRODUCTION MONITORING SHALL BE
INSTALLED AT PV & BESS SWITCHGEAR.

6. IMPACT DRIVERS ARE NOT APPROVED FOR USE ON
INVERTERS OR WIRE BOXES.

7. THE BESS WILL BE CONFIGURED TO ENSURE IT IS 100%

CHARGED FROM THE SOLAR PV SYSTEM WITH NO CHARGING
FROM THE UTILITY GRID. THIS WILL BE ACCOMPLISHED WITH

THE GELI ENERGY MANAGEMENT SYSTEM AND THE TESLA
SITE CONTROLLER SERVING AS A POWER CONTROL SYSTEM.

PROFESSIO
NA

L ENGINEER
E19765
800V 480V

PV TRANSFORMER
1500kVA, NEMA 3R, D-YG, DRY-TYPE
Z = 5.75%, X/R = 7.5

PAD MOUNTED
PVXFMR.01
480V (300 MCOV)

LIGHTNING ARRESTOR
#4/0 Cu BOND TO

GROUND RING (TYP) EXOTHERMIC BOND (TYP)
(1) 3/4" X 10' GROUNDING

ELECTRODES (TYP OF ALL

GROUND RODS)

GROUND ROD

GROUND ROD
992.5AK
MAIN

BREAKER
3000AF, 3000AT,

ELECTRONIC TRIP,
480V, 65kAIC

GFP PER
CEC 215.10,

ARC ENERGY

REDUCTION PER
CEC 240.87
SECTION 1 - MAIN
BREAKER MCB.01
2500AS
2500AF
3P
(WITH

VIEWING

WINDOW IF

REQUIRED

BY AHJ)
SECTION 4 -

PV SERVICE
FUSED

DISCONNECT
1654.9A
L

TO PV SWITCHGEAR,
SEE SHEET WP601.01

UTILITY

SERVICE
480V
480VAC, 3PH, 4W
4000A BUS, 4000A MAIN (EXST)
7 MSB

EXISTING
LOADS
(EXST)

EXISTING

PG&E METER M
8 UTILITY TRANSFORMER

INTERCONNECTION
- 3000A, 480VAC, 3ɸ
- LINE-SIDE

CONNECTION VIA

SOLAR READY

BREAKER SECTION
- PER CEC 705.11
3000AF
3000AT
3PP
2500AF
2000AT
3P
MTSTO EXISTING 1250kW GENERATOR
(KOHLER POWER SYSTEMS
MODEL: KD1250-4)

PV UTILITY DISCONNECT

EATON PRINGLE BOLTED PRESSURE
SWITCH CB-30-3-4-B-120-480-G, OAE
480V, 3000A FUSIBLE W/ 3000A FUSES,
NEMA 3R, 3P, 4W, VIEWABLE, LOCKABLE,
GFP PER CEC 230.95 W/

PERFORMANCE TESTING,

PAD MOUNTED
2 6
3000A
ACD.01
PV & BESS SWITCHGEAR (SWGR.01)
480V, 3500A BUS (OAE), NEMA 3R, 3ɸ, 4W , 65 KAIC
PER CEC 705.12(B)(3)(3), SERVICE ENTRY RATED, PAD MOUNTED 7 4000AF
4000AT
3P
N
2256.3A
LSIG
2256.3A
SECTION 2 -

BESS SERVICE

BREAKERS
800AF
800AT
3P
601.4A
M

TO BESS,

SEE SHEET
WP601.2
2500AS
2500AF
3P
M
NGOM

PER PG&E
SPECS
SECTION 3 -

PV METER
480V, 2500A, 3ɸ
5 PHOTOVOLTAIC ARRAY
(3000) QCELLS Q.PEAK DUO XL-G11S.3/BFG 595, 595W MODULES, OAE (120) STRINGS OF (25) MODULES
(5) CHINT CPS SCH275KTL-DO/US-800-36 INVERTERS - 250KW AC SELECTED RACKING SHALL BE UL 2703 LISTED AS AN EGC
BARE 6 AWG EGC ATTACHED TO RAIL ENDS WITH WEEB LUGS
1500V PV WIRE FOR ALL SOURCE WIRING

BATTERY ENERGY STORAGE SYSTEM
(1) TESLA MEGAPACK 2 XL 4HR (448.8kW/1795.2kWh)

MAIN BREAKER FOR

OVERALL SITE

SERVICE
2 2
100AF
100AT
3P
(3H, 1G, 1N)
#2 THWN-2 IN
1-1/4" PVC40, ~25'
M
(3) CT TWISTED PAIR IN
3/4" EMT, APPROX. 20'
TO AUX. POWER

PANELBOARD,
SEE SHEET WP601.4
SEL-735

BESS METER
M
SEL-735

PV METER
(1) CAT5E/6 IN 1" PVC40 ~30' (DATA)

TO GELI EMS,
SEE SHEET WP601.4
(2) CAT5E/6 IN 1" PVC40 ~275' (DATA)
(1) CAT5E/6 IN 1"
PVC40 ~25' (DATA)
M

TO ALSOENERGY DAS,
SEE SHEET WP601.1
RS-485 TWISTED PAIR IN
1" PVC40 ~725' (DATA)

LOCATED NEAR POC

LOCATED AT EQUIPMENT YARD

TO GELI EMS,
SEE SHEET WP601.4
M
(3) CT TWISTED PAIR IN
3/4" PVC40, APPROX. 20'
SEL-735 NEW

OVERALL SITE

METER FOR BESS

CONTROLLER
SEL-735 OVERALL
OUTPUT METER STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024

SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET

KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765

ELECTRICAL SLD -
POI
WP601.3
SCALE: NTS
ELECTRICAL SLD - POIA1

GENERAL SHEET NOTES

SHEET KEYNOTES

1. CONDUIT ABOVE GRADE SHALL BE EMT. ALL CONDUIT BELOW
GRADE SHALL BE PVC OR HDPE WITH RMC RISER. USE
SCHEDULE 40 FOR BELOW GRADE CONDUIT RUN UNDER
GRASSY AREAS.

2. ALL COPPER (CU) CONDUCTORS IN CONDUIT SHALL BE
THWN-2 OR XLPE. ALL EXPOSED CONDUCTORS SHALL BE
PVWIRE. ALL ALUMINUM (AL) CONDUCTORS IN CONDUIT
SHALL BE XHHW-2, OR XLPE.

3. ALUMINUM CONDUCTORS SHALL BE BRUSHED AND TREATED
WITH ANTIOXIDANT COMPOUND AT TERMINAL POINTS.

4. TORQUE: ALL CONDUCTORS LANDING IN SCREW

CONNECTIONS MUST BE PROPERLY TIGHTENED TO THE
MANUFACTURER'S TORQUE REQUIREMENTS. ALL BOLTED

CONDUCTOR TERMINATIONS MUST BE TORQUED TO THEIR
RATED VALUE. IT IS THE SUBCONTRACTOR'S

RESPONSIBILITY TO ENSURE ALL CONDUCTORS WITH

TORQUE REQUIREMENTS HAVE BEEN MARKED WITH A PAINT

PEN OR PERMANENT MARKER

AT THE TIME THAT THE
TORQUE TEST WAS DONE.

5. SOLAR ENERGY PRODUCTION MONITORING SHALL BE
INSTALLED AT PV & BESS SWITCHGEAR.

6. IMPACT DRIVERS ARE NOT APPROVED FOR USE ON
INVERTERS OR WIRE BOXES.

7. THE BESS WILL BE CONFIGURED TO ENSURE IT IS 100%

CHARGED FROM THE SOLAR PV SYSTEM WITH NO CHARGING
FROM THE UTILITY GRID. THIS WILL BE ACCOMPLISHED WITH

THE GELI ENERGY MANAGEMENT SYSTEM AND THE TESLA
SITE CONTROLLER SERVING AS A POWER CONTROL SYSTEM.

1. EQUIPMENT SHALL BE INSTALLED AND LABELED IN

ACCORDANCE WITH THE CEC AND ALL APPLICABLE

REQUIREMENTS OF THE SERVING UTILITY COMPANY AND
LOCAL AUTHORITY HAVING JURISDICTION (AHJ).

3. LISTING AGENCY NAMES AND NUMBERS TO BE INDICATED ON
POWER INVERTER AND SOLAR MODULES PER CEC 110.3(B).

4. LABELED "PHOTOVOLTAIC SYSTEM AC COMBINER."

5. UTILITY METER LABELED "PHOTOVOLTAIC SYSTEM
MONITOR.” CT COMPARTMENT PER EUSERC 322, 330. METER
DOOR PER EUSERC 333. METER SOCKET IS 15J.

6. LABELED “PHOTOVOLTAIC SYSTEM UTILITY DISCONNECT”

SWITCH TO BE VISUAL OPEN AND ACCESSIBLE AND
CONFORM TO CEC 705.22.

7. LABELED “WARNING: THIS PANEL SUPPLIED BY MULTIPLE
SOURCES OF POWER: 1. UTILITY POWER, 2. PHOTOVOLTAIC
SYSTEM - DISCONNECT ALL SOURCES BEFORE SERVICING.”

8. POINT OF INTERCONNECTION SHALL BE IN ACCORDANCE
WITH CEC 705.11. SOLAR-READY BREAKER TO HAVE GROUND
FAULT PROTECTION PER CEC 215.10 AND ARC ENERGY
REDUCTION PER CEC 240.87.

9. PROVIDE IDENTIFICATION ALONG WITH POSITIVE & NEGATIVE CONDUCTORS PER CEC 210.5(C)(2).

10. MINIMUM BENDING RADIUS OF PHOTOVOLTAIC MODULE

LEADS SHALL CONFORM WITH MINIMUM BENDING RADIUS

SET FORTH BY THE MODULE MANUFACTURER OR ARTICLE
338.24, WHICHEVER IS MORE STRINGENT.

11. MATING CONNECTORS FOR PV SOURCE CIRCUITS, PV

JUMPER CABLES, AND MODULE LEVEL POWER ELECTRONICS

TO BE LISTED AND IDENTIFIED FOR INTERMATABILITY, AS
DESCRIBED IN MANUFACTURER'S INSTRUCTIONS. MATING

CONNECTORS THAT ARE NOT LISTED ARE NOT TO BE
UTILIZED FOR PROJECT.

12. AC POWER CONDUITS TO CONVEY (3) CURRENT CARRYING
CONDUCTORS AND AN EGC. NO NEUTRAL REQUIRED.

13. ALL INVERTERS ARE TO HAVE THE MAX 250kW AC OUTPUT
OPTION SELECTED. REFER TO INVERTER DATA SHEET ON
SHEET WK801.

PROFESSIO
NA

L ENGINEER
E19765
20A/1P
20A/3P
20A/1P
AUX. POWER PANELBOARD
480V, 100A BUS,
NEMA 3R,
CEC 705.12(B)(3)(3)

RACK MOUNTED AT EQUIPMENT YARD
20A/3P
SURGE

ARRESTOR
TO SWGR.01
SEE SHEET WP601.3
(3+G) #12AWG Cu THWN-2,
IN 1" EMT ~ 10'
(3+G) #12AWG THWN-2,
IN 1" EMT ~ 15'
(4+G) #2 THWN-2, #2 Cu GROUND
IN 1 1/4" PVC40 ~ 25'
15A/2P
15A/2P

GELI ENERGY

MANAGEMENT
SYSTEM

TESLA SITE

CONTROLLER
LAN2
LAN1
(1) CAT5E/6 IN 1"
EMT ~10' (DATA)
(1) CAT5E/6 IN 1" PVC40 ~25' (DATA)
BACKUP 24VDC TO
TERMINAL 5 IN CUSTOMER

INTERFACE BOARD IN
BESS.01 ON WP601.2
BESS.01 COMM.

BOARD ON WP601.2
SHIELDED CAT5E/6,
(1) #14AWG IN 1" PVC40
~50' (DATA, 24VDC)

PV METER

BESS METER

SITE METER/

OVERALL

OUTPUT METER
(1) CAT5E/6 IN 1" PVC40 ~30' (DATA)
(2) CAT5E/6 IN 1" PVC40 ~275' (DATA)
(2+G) #12AWG Cu THWN-2,
IN 1" EMT ~ 10'

ALSO ENERGY
REMOTE

ENCLOSURE

FOR BESS
(1) CAT5E/6 IN 1"
EMT ~10' (DATA)
STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024

SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET

KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765

ELECTRICAL SLD -
LV
WP601.4
SCALE: NTS
ELECTRICAL SLD - LVA1

GENERAL SHEET NOTES

SHEET KEYNOTES

1. EQUIPMENT SHALL BE INSTALLED AND LABELED IN

ACCORDANCE WITH THE CEC AND ALL APPLICABLE

REQUIREMENTS OF THE SERVING UTILITY COMPANY AND
LOCAL AUTHORITY HAVING JURISDICTION (AHJ).

3. LISTING AGENCY NAMES AND NUMBERS TO BE INDICATED ON
POWER INVERTER AND SOLAR MODULES PER CEC 110.3(B).

4. LABELED "PHOTOVOLTAIC SYSTEM AC COMBINER."

5. UTILITY METER LABELED "PHOTOVOLTAIC SYSTEM
MONITOR.” CT COMPARTMENT PER EUSERC 322, 330. METER
DOOR PER EUSERC 333. METER SOCKET IS 15J.

6. LABELED “PHOTOVOLTAIC SYSTEM UTILITY DISCONNECT”

SWITCH TO BE VISUAL OPEN AND ACCESSIBLE AND
CONFORM TO CEC 705.22.

7. LABELED “WARNING: THIS PANEL SUPPLIED BY MULTIPLE
SOURCES OF POWER: 1. UTILITY POWER, 2. PHOTOVOLTAIC
SYSTEM - DISCONNECT ALL SOURCES BEFORE SERVICING.”

8. POINT OF INTERCONNECTION SHALL BE IN ACCORDANCE
WITH CEC 705.11. SOLAR-READY BREAKER TO HAVE GROUND
FAULT PROTECTION PER CEC 215.10 AND ARC ENERGY
REDUCTION PER CEC 240.87.

9. PROVIDE IDENTIFICATION ALONG WITH POSITIVE & NEGATIVE CONDUCTORS PER CEC 210.5(C)(2).

10. MINIMUM BENDING RADIUS OF PHOTOVOLTAIC MODULE

LEADS SHALL CONFORM WITH MINIMUM BENDING RADIUS

SET FORTH BY THE MODULE MANUFACTURER OR ARTICLE
338.24, WHICHEVER IS MORE STRINGENT.

11. MATING CONNECTORS FOR PV SOURCE CIRCUITS, PV

JUMPER CABLES, AND MODULE LEVEL POWER ELECTRONICS

TO BE LISTED AND IDENTIFIED FOR INTERMATABILITY, AS
DESCRIBED IN MANUFACTURER'S INSTRUCTIONS. MATING

CONNECTORS THAT ARE NOT LISTED ARE NOT TO BE
UTILIZED FOR PROJECT.

12. AC POWER CONDUITS TO CONVEY (3) CURRENT CARRYING
CONDUCTORS AND AN EGC. NO NEUTRAL REQUIRED.

13. ALL INVERTERS ARE TO HAVE THE MAX 250kW AC OUTPUT
OPTION SELECTED. REFER TO INVERTER DATA SHEET ON
SHEET WK801.

1. CONDUIT ABOVE GRADE SHALL BE EMT. ALL CONDUIT BELOW
GRADE SHALL BE PVC OR HDPE WITH RMC RISER. USE
SCHEDULE 40 FOR BELOW GRADE CONDUIT RUN UNDER
GRASSY AREAS.

2. ALL COPPER (CU) CONDUCTORS IN CONDUIT SHALL BE
THWN-2 OR XLPE. ALL EXPOSED CONDUCTORS SHALL BE
PVWIRE. ALL ALUMINUM (AL) CONDUCTORS IN CONDUIT
SHALL BE XHHW-2, OR XLPE.

3. ALUMINUM CONDUCTORS SHALL BE BRUSHED AND TREATED
WITH ANTIOXIDANT COMPOUND AT TERMINAL POINTS.

4. TORQUE: ALL CONDUCTORS LANDING IN SCREW

CONNECTIONS MUST BE PROPERLY TIGHTENED TO THE
MANUFACTURER'S TORQUE REQUIREMENTS. ALL BOLTED

CONDUCTOR TERMINATIONS MUST BE TORQUED TO THEIR
RATED VALUE. IT IS THE SUBCONTRACTOR'S

RESPONSIBILITY TO ENSURE ALL CONDUCTORS WITH

TORQUE REQUIREMENTS HAVE BEEN MARKED WITH A PAINT

PEN OR PERMANENT MARKER

AT THE TIME THAT THE
TORQUE TEST WAS DONE.

5. SOLAR ENERGY PRODUCTION MONITORING SHALL BE
INSTALLED AT PV & BESS SWITCHGEAR.

6. IMPACT DRIVERS ARE NOT APPROVED FOR USE ON
INVERTERS OR WIRE BOXES.

7. THE BESS WILL BE CONFIGURED TO ENSURE IT IS 100%

CHARGED FROM THE SOLAR PV SYSTEM WITH NO CHARGING
FROM THE UTILITY GRID. THIS WILL BE ACCOMPLISHED WITH

THE GELI ENERGY MANAGEMENT SYSTEM AND THE TESLA
SITE CONTROLLER SERVING AS A POWER CONTROL SYSTEM.

PROFESSIO
NA

L ENGINEER
E19765
DC
AC
_ +_
++ +
_ _

18.8A
198.5A
TO ACC.XX
COMM
TO INV.XX
(CAT6)
ɸ1
ɸ2
ɸ3
G
TO INV.XX
(CAT6)
A
G
XX
MPPT112 25 +
_
_ +_
++ +
_ _
MPPT2+
_
_ +_
++ +
_ _
MPPT3+
_
25A
12 25

18.8A12 25
12 25

18.8A12 25
12 25
_ +_
++ +
_ _

18.8A
A
MPPT412 25 +
_
_ +_
++ +
_ _
MPPT5+
_
_ +_
++ +
_ _
MPPT6+
_
25A
12 25

18.8A12 25
12 25

18.8A12 25
12 25
_ +_
++ +
_ _

18.8A
A
MPPT712 25 +
_
_ +_
++ +
_ _
MPPT8+
_
_ +_
++ +
_ _
MPPT9+
_
25A
12 25

18.8A12 25
12 25

18.8A12 25
12 25
_ +_
++ +
_ _

18.8A
A
MPPT1012 25 +
_
_ +_
++ +
_ _
MPPT11+
_
_ +_
++ +
_ _
MPPT12+
_
25A
12 25

18.8A12 25
12 25

18.8A12 25
12 25
CHINT SCA275KTL-DO/US-800-36
800V 3PH-3W-198.5A AC OUTPUT,

DC & AC SURGE ARRESTORS,
AFCI - RACK MOUNTED INV.01 - INV.05
1 3 13
1 3 9 10 11
12 ɸ1 ɸ2 ɸ3 G
ɸ1
ɸ2
ɸ3
G
TO INV.01
198.5A
B
ɸ1
ɸ2
ɸ3
G
TO INV.02
198.5A
C
250A/3P
250A/3P
G
397.0A
AC COMBINER (ACC.01)
800V, 1000A BUS (OAE)
NEMA 3R, 3W,
(2) 250A 100% RATED BREAKERS
CEC 705.12(B)(3)(3)
RACK MOUNTED 4 7
ɸ1 ɸ2 ɸ3 G
ɸ1
ɸ2
ɸ3
G
TO INV.03
198.5A
D
ɸ1
ɸ2
ɸ3
G
TO INV.04
198.5A
E
ɸ1
ɸ2
ɸ3
G
TO INV.05
198.5A
F
250A/3P
250A/3P
250A/3P
H
595.5A
AC COMBINER (ACC.02)
800V, 1000A BUS (OAE)
NEMA 3R, 3W,
(3) 250A 100% RATED BREAKERS
CEC 705.12(B)(3)(3)
RACK MOUNTED 4 7
TO ACRC.01,

REFER TO
SHEET WP602.2
TO ACRC.01,

REFER TO
SHEET WP602.2
STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024

SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET

KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765
ELECTRICAL 3LD
WP602.1
ELECTRICAL 3LD
WP602.1
Scale: NTS
ELECTRICAL 3LD - INVERTERSA1

GENERAL SHEET NOTES

SHEET KEYNOTES

WIRE LEGEND
CONDUCTOR 277/480V, 3PH, 4W 120/208V, 3PH, 4W 120/240V, 3PH, 3W AC ɸ1 BROWN BLACK BLACK
AC ɸ2 ORANGE/PURPLE RED ORANGE
AC ɸ3 YELLOW BLUE BLUE

AC NEUTRAL GRAY WHITE WHITE

DC POSITIVE RED RED RED

DC NEGATIVE BLACK BLACK BLACK

GROUND GREEN GREEN GREEN
NOTE: AC WIRE INSULATION COLORS SHALL MATCH THE EXISTING BUILDING(S) AND COMPLY WITH THE LATEST VERSION OF THE CEC ELECTRICAL CODE.

1. EQUIPMENT SHALL BE INSTALLED AND LABELED IN

ACCORDANCE WITH THE CEC AND ALL APPLICABLE

REQUIREMENTS OF THE SERVING UTILITY COMPANY AND
LOCAL AUTHORITY HAVING JURISDICTION (AHJ).

2. DISCONNECTS MUST COMPLY WITH CEC 690.15 AND PROVIDE
WARNING SIGN PER CEC 690.13. FUSED DISCONNECT SWITCH
TO HAVE GROUND FAULT PROTECTION PER CEC 230.95 AND
ARC ENERGY REDUCTION PER CEC 240.67.

3. LISTING AGENCY NAMES AND NUMBERS TO BE INDICATED ON
POWER INVERTER AND SOLAR MODULES PER CEC 110.3(B).

4. LABELED "PHOTOVOLTAIC SYSTEM AC COMBINER."

5. UTILITY METER LABELED "PHOTOVOLTAIC SYSTEM
MONITOR.” CT COMPARTMENT PER EUSERC 322, 330. METER
DOOR PER EUSERC 333. METER SOCKET IS 15J.

6. LABELED “PHOTOVOLTAIC SYSTEM UTILITY DISCONNECT”

SWITCH TO BE VISUAL OPEN AND ACCESSIBLE AND
CONFORM TO CEC 705.22.

7. LABELED “WARNING: THIS PANEL SUPPLIED BY MULTIPLE
SOURCES OF POWER: 1. UTILITY POWER, 2. PHOTOVOLTAIC
SYSTEM - DISCONNECT ALL SOURCES BEFORE SERVICING.”

8. POINT OF INTERCONNECTION SHALL BE IN ACCORDANCE
WITH CEC 705.11. SOLAR-READY BREAKER TO HAVE GROUND
FAULT PROTECTION PER CEC 215.10 AND ARC ENERGY
REDUCTION PER CEC 240.87.

9. PROVIDE IDENTIFICATION ALONG WITH POSITIVE & NEGATIVE CONDUCTORS PER CEC 210.5(C)(2).

10. MINIMUM BENDING RADIUS OF PHOTOVOLTAIC MODULE

LEADS SHALL CONFORM WITH MINIMUM BENDING RADIUS

SET FORTH BY THE MODULE MANUFACTURER OR ARTICLE
338.24, WHICHEVER IS MORE STRINGENT.

11. MINIMUM CONNECTORS FOR PV SOURCE CIRCUITS, PV

JUMPER CABLES, AND MODULE LEVEL POWER ELECTRONICS

TO BE LISTED AND IDENTIFIED FOR INTERMATABILITY, AS
DESCRIBED IN MANUFACTURER'S INSTRUCTIONS. MATING

CONNECTORS THAT ARE NOT LISTED ARE NOT TO BE
UTILIZED FOR PROJECT.

12. AC POWER CONDUITS TO CONVEY (3) CURRENT CARRYING
CONDUCTORS AND AN EGC. NO NEUTRAL REQUIRED.

13. ALL INVERTERS ARE TO HAVE THE MAX 250kW AC OUTPUT
OPTION SELECTED. REFER TO INVERTER DATA SHEET ON
WK801.

Scale: NTS
ELECTRICAL 3LD - AC COMBINERSA3

1. CONDUIT ABOVE GRADE SHALL BE EMT. ALL CONDUIT BELOW
GRADE SHALL BE PVC OR HDPE WITH RMC RISER. USE
SCHEDULE 40 FOR BELOW GRADE CONDUIT RUN UNDER
GRASSY AREAS.

2. ALL COPPER (CU) CONDUCTORS IN CONDUIT SHALL BE
THWN-2 OR XLPE. ALL EXPOSED CONDUCTORS SHALL BE
PVWIRE. ALL ALUMINUM (AL) CONDUCTORS IN CONDUIT
SHALL BE XHHW-2, OR XLPE.

3. ALUMINUM CONDUCTORS SHALL BE BRUSHED AND TREATED
WITH ANTIOXIDANT COMPOUND AT TERMINAL POINTS.

4. TORQUE: ALL CONDUCTORS LANDING IN SCREW

CONNECTIONS MUST BE PROPERLY TIGHTENED TO THE
MANUFACTURER'S TORQUE REQUIREMENTS. ALL BOLTED

CONDUCTOR TERMINATIONS MUST BE TORQUED TO THEIR
RATED VALUE. IT IS THE SUBCONTRACTOR'S

RESPONSIBILITY TO ENSURE ALL CONDUCTORS WITH

TORQUE REQUIREMENTS HAVE BEEN MARKED WITH A PAINT

PEN OR PERMANENT MARKER

AT THE TIME THAT THE
TORQUE TEST WAS DONE.

5. SOLAR ENERGY PRODUCTION MONITORING SHALL BE
INSTALLED AT PV & BESS SWITCHGEAR.

6. IMPACT DRIVERS ARE NOT APPROVED FOR USE ON
INVERTERS OR WIRE BOXES.

7. THE BESS WILL BE CONFIGURED TO ENSURE IT IS 100%

CHARGED FROM THE SOLAR PV SYSTEM WITH NO CHARGING
FROM THE UTILITY GRID. THIS WILL BE ACCOMPLISHED WITH

THE GELI ENERGY MANAGEMENT SYSTEM AND THE TESLA
SITE CONTROLLER SERVING AS A POWER CONTROL SYSTEM.

PROFESSIO
NA

L ENGINEER
E19765
SECTION 2 - ACRC
(1) 750A, 3P BREAKER
(1) 500A, 3P BREAKER
(2) 20A, 3P BREAKERS
(1) 20A, 2P BREAKER
SECTION 1 - SERVICE
DISCONNECT ACD.02
GFP PER CEC 215.10,

ARC ENERGY REDUCTION
PER CEC 240.87
ɸ1 ɸ2 ɸ3 G
500A/3P
750A/3P
(1) 3/4" X 10' GROUNDING

ELECTRODES (TYP OF ALL

GROUND RODS)

GROUND ROD EXOTHERMIC BOND (TYP)

GROUND ROD
GROUND
ROD
TO ACC.01,

REFER TO SHEET
WP602.1
G 397.0A
H
TO ACC.02,

REFER TO SHEET
WP602.1
595.A
PV SWITCHGEAR (SWGR.02)
800V, 1400A BUS (OAE),
NEMA 3R, 3ɸ, 3W , 65 KAIC
PER CEC 705.12(B)(3)(3)

SERVICE ENTRY RATED

PAD MOUNTED
74 20A/3P
SPD
24DC/120V
DATA
LOGGER

ALSO ENERGY

MONITORING BOX
(COMM.01)

GSM CELL
MODEM
(1) SHIELDED CAT6,
APPROX 10' IN 3/4" EMT
RS-485 TWISTED PAIR/24V,
(2) BELDEN 3106A OAE,
APPROX 65' IN 3/4" PVC40
RS-485 IN 1" EMT/PVC40 ~315'TO INV.01 - INV.02
RS-485 IN 1" EMT/PVC40 ~80'TO INV.03 - INV.05
(2H, 1G) #14 THWN-2
IN 3/4" PVC40, APPROX. 10'
24DC/120V
800V/120V

CPS-AC-PLC
FLEX

GATEWAY

CHINT PLC

ENCLOSURE
01 (PLC.01)
NEMA 3R
120V SERVICE
OUTLET
ɸ1 ɸ2 ɸ3 G
ɸ1 N G
5KVA, 800V
TO 120V XFMR
20A/1P
20A/1P

AUXILIARY

POWER PANEL
20A/2P
20A/3P
(3H, 1G) #10 THWN-2
IN 3/4" PVC40, APPROX. 10'
(1H, 1N, 1G) #10 THWN-2
IN 3/4" EMT, APPROX. 10'
(1H, 1N, 1G) #10 THWN-2
IN 3/4" EMT, APPROX. 10'(1H, 1N, 1G) #10 THWN-2
IN 3/4" EMT, APPROX. 10'
#4/0 Cu BOND TO

GROUND RING (TYP)

GROUND ROD

TO PV XFMR,

REFER TO
SHEET WP602.4
K992.5A 12
FROM SEL-735 PV METER
SEE SHEET WP602.4
RS-485 TWISTED PAIR
IN 1" PVC40 ~725' (DATA)

WEATHER

STATION
(MOUNTED AT

ARRAY B)
IGHI
IBOM
TAMB.

VWIND
POA SENSOR (Si-RS485TC-2T-v-MB)
AND T-BOM SENSOR (Tmodul-Si) TO

MATCH THE TILT AND ORIENTATION

OF THE MODULES
1600AF
1350AT
3P
STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024

SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET

KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765
ELECTRICAL 3LD
WP602.2
ELECTRICAL 3LD
WP602.2
Scale: NTS
ELECTRICAL 3LD - PV SWITCHGEARA1

GENERAL SHEET NOTES

SHEET KEYNOTES

WIRE LEGEND
CONDUCTOR 277/480V, 3PH, 4W 120/208V, 3PH, 4W 120/240V, 3PH, 3W AC ɸ1 BROWN BLACK BLACK
AC ɸ2 ORANGE/PURPLE RED ORANGE
AC ɸ3 YELLOW BLUE BLUE

AC NEUTRAL GRAY WHITE WHITE

DC POSITIVE RED RED RED

DC NEGATIVE BLACK BLACK BLACK

GROUND GREEN GREEN GREEN
NOTE: AC WIRE INSULATION COLORS SHALL MATCH THE EXISTING BUILDING(S) AND COMPLY WITH THE LATEST VERSION OF THE CEC ELECTRICAL CODE.

1. EQUIPMENT SHALL BE INSTALLED AND LABELED IN

ACCORDANCE WITH THE CEC AND ALL APPLICABLE

REQUIREMENTS OF THE SERVING UTILITY COMPANY AND
LOCAL AUTHORITY HAVING JURISDICTION (AHJ).

2. DISCONNECTS MUST COMPLY WITH CEC 690.15 AND PROVIDE
WARNING SIGN PER CEC 690.13. FUSED DISCONNECT SWITCH
TO HAVE GROUND FAULT PROTECTION PER CEC 230.95 AND
ARC ENERGY REDUCTION PER CEC 240.67.

3. LISTING AGENCY NAMES AND NUMBERS TO BE INDICATED ON
POWER INVERTER AND SOLAR MODULES PER CEC 110.3(B).

4. LABELED "PHOTOVOLTAIC SYSTEM AC COMBINER."

5. UTILITY METER LABELED "PHOTOVOLTAIC SYSTEM
MONITOR.” CT COMPARTMENT PER EUSERC 322, 330. METER
DOOR PER EUSERC 333. METER SOCKET IS 15J.

6. LABELED “PHOTOVOLTAIC SYSTEM UTILITY DISCONNECT”

SWITCH TO BE VISUAL OPEN AND ACCESSIBLE AND
CONFORM TO CEC 705.22.

7. LABELED “WARNING: THIS PANEL SUPPLIED BY MULTIPLE
SOURCES OF POWER: 1. UTILITY POWER, 2. PHOTOVOLTAIC
SYSTEM - DISCONNECT ALL SOURCES BEFORE SERVICING.”

8. POINT OF INTERCONNECTION SHALL BE IN ACCORDANCE
WITH CEC 705.11. SOLAR-READY BREAKER TO HAVE GROUND
FAULT PROTECTION PER CEC 215.10 AND ARC ENERGY
REDUCTION PER CEC 240.87.

9. PROVIDE IDENTIFICATION ALONG WITH POSITIVE & NEGATIVE CONDUCTORS PER CEC 210.5(C)(2).

10. MINIMUM BENDING RADIUS OF PHOTOVOLTAIC MODULE

LEADS SHALL CONFORM WITH MINIMUM BENDING RADIUS

SET FORTH BY THE MODULE MANUFACTURER OR ARTICLE
338.24, WHICHEVER IS MORE STRINGENT.

11. MINIMUM CONNECTORS FOR PV SOURCE CIRCUITS, PV

JUMPER CABLES, AND MODULE LEVEL POWER ELECTRONICS

TO BE LISTED AND IDENTIFIED FOR INTERMATABILITY, AS
DESCRIBED IN MANUFACTURER'S INSTRUCTIONS. MATING

CONNECTORS THAT ARE NOT LISTED ARE NOT TO BE
UTILIZED FOR PROJECT.

12. AC POWER CONDUITS TO CONVEY (3) CURRENT CARRYING
CONDUCTORS AND AN EGC. NO NEUTRAL REQUIRED.

13. ALL INVERTERS ARE TO HAVE THE MAX 250kW AC OUTPUT
OPTION SELECTED. REFER TO INVERTER DATA SHEET ON
WK801.

1. CONDUIT ABOVE GRADE SHALL BE EMT. ALL CONDUIT BELOW
GRADE SHALL BE PVC OR HDPE WITH RMC RISER. USE
SCHEDULE 40 FOR BELOW GRADE CONDUIT RUN UNDER
GRASSY AREAS.

2. ALL COPPER (CU) CONDUCTORS IN CONDUIT SHALL BE
THWN-2 OR XLPE. ALL EXPOSED CONDUCTORS SHALL BE
PVWIRE. ALL ALUMINUM (AL) CONDUCTORS IN CONDUIT
SHALL BE XHHW-2, OR XLPE.

3. ALUMINUM CONDUCTORS SHALL BE BRUSHED AND TREATED
WITH ANTIOXIDANT COMPOUND AT TERMINAL POINTS.

4. TORQUE: ALL CONDUCTORS LANDING IN SCREW

CONNECTIONS MUST BE PROPERLY TIGHTENED TO THE
MANUFACTURER'S TORQUE REQUIREMENTS. ALL BOLTED

CONDUCTOR TERMINATIONS MUST BE TORQUED TO THEIR
RATED VALUE. IT IS THE SUBCONTRACTOR'S

RESPONSIBILITY TO ENSURE ALL CONDUCTORS WITH

TORQUE REQUIREMENTS HAVE BEEN MARKED WITH A PAINT

PEN OR PERMANENT MARKER

AT THE TIME THAT THE
TORQUE TEST WAS DONE.

5. SOLAR ENERGY PRODUCTION MONITORING SHALL BE
INSTALLED AT PV & BESS SWITCHGEAR.

6. IMPACT DRIVERS ARE NOT APPROVED FOR USE ON
INVERTERS OR WIRE BOXES.

7. THE BESS WILL BE CONFIGURED TO ENSURE IT IS 100%

CHARGED FROM THE SOLAR PV SYSTEM WITH NO CHARGING
FROM THE UTILITY GRID. THIS WILL BE ACCOMPLISHED WITH

THE GELI ENERGY MANAGEMENT SYSTEM AND THE TESLA
SITE CONTROLLER SERVING AS A POWER CONTROL SYSTEM.

PROFESSIO
NA

L ENGINEER
E19765

BATTERY
MODULE

THERMAL

CABINET

INTERFACE
BAY
DC
AC
DC
AC
DC
AC
DC
AC
COMM

BATTERY
MODULE

BATTERY
MODULE
DC
AC
DC
AC
DC
AC
DC
AC
EXOTHERMIC BOND (TYP) 3/4" X 10' GROUNDING

ELECTRODES (TYP)

GROUND ROD

GROUND ROD
604.1A
LVA
TESLA MEGAPACK 2 XL (5.4.6.A/AB-448.8-1795.2)
480V, 448.8kW/1795.2kWh,
693kVA RATED, NEMA 3R

PAD MOUNTED
1600A/3P ɸ1
ɸ2
ɸ3
TO SWGR.01,

REFER TO
SHEET WP602.4
M
ɸ1 ɸ2 ɸ3 N G
15A/2P
20A/3P
15A/2P
SPD
AUX. POWER PANELBOARD
480V, 100A BUS,
NEMA 3R, CEC
705.12(B)(3)(3)

GELI ENERGY

MANAGEMENT
SYSTEM

TESLA SITE

CONTROLLER
LAN2
20A/3P
SPARE
20A/1P
20A/1P
SPARE
(4+G) #2 THWN-2, #2 Cu GROUND
IN 1 1/4" PVC40 ~ 25'
TO SWGR.01,

REFER TO
SHEET WP602.4
SHIELDED CAT5E/6,
(1) #14AWG IN 1" PVC40
~50' (DATA, 24VDC)
LAN1
(1) CAT5E/6 IN 1" EMT ~10' (DATA)

PV METER

BESS METER

SITE METER/

OVERALL

OUTPUT METER

ALSO ENERGY
REMOTE

ENCLOSURE

FOR BESS
(1) CAT5E/6 IN 1" EMT ~10' (DATA)
(1) CAT5E/6 IN 1" PVC40 ~25' (DATA)
(1) CAT5E/6 IN 1" PVC40 ~30' (DATA)
(2) CAT5E/6 IN 1" PVC40 ~275' (DATA)
STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024
SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET
KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765
ELECTRICAL 3LD
WP602.3
ELECTRICAL 3LD
WP602.3
Scale: NTS
ELECTRICAL 3LD - BESSA1

GENERAL SHEET NOTES

SHEET KEYNOTES

WIRE LEGEND
CONDUCTOR 277/480V, 3PH, 4W 120/208V, 3PH, 4W 120/240V, 3PH, 3W AC ɸ1 BROWN BLACK BLACK
AC ɸ2 ORANGE/PURPLE RED ORANGE
AC ɸ3 YELLOW BLUE BLUE

AC NEUTRAL GRAY WHITE WHITE

DC POSITIVE RED RED RED

DC NEGATIVE BLACK BLACK BLACK

GROUND GREEN GREEN GREEN
NOTE: AC WIRE INSULATION COLORS SHALL MATCH THE EXISTING BUILDING(S) AND COMPLY WITH THE LATEST VERSION OF THE CEC ELECTRICAL CODE.

1. EQUIPMENT SHALL BE INSTALLED AND LABELED IN

ACCORDANCE WITH THE CEC AND ALL APPLICABLE

REQUIREMENTS OF THE SERVING UTILITY COMPANY AND
LOCAL AUTHORITY HAVING JURISDICTION (AHJ).

2. DISCONNECTS MUST COMPLY WITH CEC 690.15 AND PROVIDE
WARNING SIGN PER CEC 690.13. FUSED DISCONNECT SWITCH
TO HAVE GROUND FAULT PROTECTION PER CEC 230.95 AND
ARC ENERGY REDUCTION PER CEC 240.67.

3. LISTING AGENCY NAMES AND NUMBERS TO BE INDICATED ON
POWER INVERTER AND SOLAR MODULES PER CEC 110.3(B).

4. LABELED "PHOTOVOLTAIC SYSTEM AC COMBINER."

5. UTILITY METER LABELED "PHOTOVOLTAIC SYSTEM
MONITOR.” CT COMPARTMENT PER EUSERC 322, 330. METER
DOOR PER EUSERC 333. METER SOCKET IS 15J.

6. LABELED “PHOTOVOLTAIC SYSTEM UTILITY DISCONNECT”

SWITCH TO BE VISUAL OPEN AND ACCESSIBLE AND
CONFORM TO CEC 705.22.

7. LABELED “WARNING: THIS PANEL SUPPLIED BY MULTIPLE
SOURCES OF POWER: 1. UTILITY POWER, 2. PHOTOVOLTAIC
SYSTEM - DISCONNECT ALL SOURCES BEFORE SERVICING.”

8. POINT OF INTERCONNECTION SHALL BE IN ACCORDANCE
WITH CEC 705.11. SOLAR-READY BREAKER TO HAVE GROUND
FAULT PROTECTION PER CEC 215.10 AND ARC ENERGY
REDUCTION PER CEC 240.87.

9. PROVIDE IDENTIFICATION ALONG WITH POSITIVE & NEGATIVE CONDUCTORS PER CEC 210.5(C)(2).

10. MINIMUM BENDING RADIUS OF PHOTOVOLTAIC MODULE

LEADS SHALL CONFORM WITH MINIMUM BENDING RADIUS

SET FORTH BY THE MODULE MANUFACTURER OR ARTICLE
338.24, WHICHEVER IS MORE STRINGENT.

11. MINIMUM CONNECTORS FOR PV SOURCE CIRCUITS, PV

JUMPER CABLES, AND MODULE LEVEL POWER ELECTRONICS

TO BE LISTED AND IDENTIFIED FOR INTERMATABILITY, AS
DESCRIBED IN MANUFACTURER'S INSTRUCTIONS. MATING

CONNECTORS THAT ARE NOT LISTED ARE NOT TO BE
UTILIZED FOR PROJECT.

12. AC POWER CONDUITS TO CONVEY (3) CURRENT CARRYING
CONDUCTORS AND AN EGC. NO NEUTRAL REQUIRED.

13. ALL INVERTERS ARE TO HAVE THE MAX 250kW AC OUTPUT
OPTION SELECTED. REFER TO INVERTER DATA SHEET ON
WK801.

1. CONDUIT ABOVE GRADE SHALL BE EMT. ALL CONDUIT BELOW
GRADE SHALL BE PVC OR HDPE WITH RMC RISER. USE
SCHEDULE 40 FOR BELOW GRADE CONDUIT RUN UNDER
GRASSY AREAS.

2. ALL COPPER (CU) CONDUCTORS IN CONDUIT SHALL BE
THWN-2 OR XLPE. ALL EXPOSED CONDUCTORS SHALL BE
PVWIRE. ALL ALUMINUM (AL) CONDUCTORS IN CONDUIT
SHALL BE XHHW-2, OR XLPE.

3. ALUMINUM CONDUCTORS SHALL BE BRUSHED AND TREATED
WITH ANTIOXIDANT COMPOUND AT TERMINAL POINTS.

4. TORQUE: ALL CONDUCTORS LANDING IN SCREW

CONNECTIONS MUST BE PROPERLY TIGHTENED TO THE
MANUFACTURER'S TORQUE REQUIREMENTS. ALL BOLTED

CONDUCTOR TERMINATIONS MUST BE TORQUED TO THEIR
RATED VALUE. IT IS THE SUBCONTRACTOR'S

RESPONSIBILITY TO ENSURE ALL CONDUCTORS WITH

TORQUE REQUIREMENTS HAVE BEEN MARKED WITH A PAINT

PEN OR PERMANENT MARKER

AT THE TIME THAT THE
TORQUE TEST WAS DONE.

5. SOLAR ENERGY PRODUCTION MONITORING SHALL BE
INSTALLED AT PV & BESS SWITCHGEAR.

6. IMPACT DRIVERS ARE NOT APPROVED FOR USE ON
INVERTERS OR WIRE BOXES.

7. THE BESS WILL BE CONFIGURED TO ENSURE IT IS 100%

CHARGED FROM THE SOLAR PV SYSTEM WITH NO CHARGING
FROM THE UTILITY GRID. THIS WILL BE ACCOMPLISHED WITH

THE GELI ENERGY MANAGEMENT SYSTEM AND THE TESLA
SITE CONTROLLER SERVING AS A POWER CONTROL SYSTEM.

PROFESSIO
NA

L ENGINEER
E19765
ɸ1 ɸ2 ɸ3 N G
SECTION 4 -

PV SERVICE
FUSED

DISCONNECT
2500AS
2500AF
3P
(WITH

VIEWING

WINDOW IF

REQUIRED

BY AHJ)
2 SECTION 3 -

PV METER
480V, 2500A, 3ɸ
2500AS
2500AF
3P
2 NGOM

PER PG&E
SPECS
M
800AF
800AT
3P
601.4A

TO BESS,

REFER TO
SHEET WP602.3
M
100AF
100AT
3P
SECTION 2 -

BESS SERVICE

BREAKERS
MAIN

BREAKER
3000AF, 3000AT,

ELECTRONIC TRIP,
480V, 65kAIC

GFP PER
CEC 215.10,

ARC ENERGY

REDUCTION PER
CEC 240.87
SECTION 1 - MAIN

BREAKER

PV TRANSFORMER
1500kVA, NEMA 3R, D-YG,
DRY-TYPE Z = 5.75%, X/R = 7.5

PAD MOUNTED
K
ɸ1
ɸ2
ɸ3
N
G
1500KVA
800V 480V 1654.9A
480V (300 MCOV)

LIGHTNING ARRESTOR
992.5A

TO PV SWITCHGEAR,
SEE SHEET WP602.2
L
TO ACD.01,

REFER TO
SHEET WP602.5
N
2256.3A

EXOTHERMIC BOND (TYP)
(1) 3/4" X 10' GROUNDING

ELECTRODES (TYP OF ALL

GROUND RODS)

GROUND ROD

GROUND ROD
#4/0 Cu BOND TO

GROUND RING (TYP)
PV & BESS SWITCHGEAR (SWGR.01)
480V, 3500A BUS (OAE),
NEMA 3R, 3ɸ, 4W , 65 KAIC
PER CEC 705.12(B)(3)(3)

SERVICE ENTRY RATED

PAD MOUNTED
7 M
(3H, 1G, 1N) #2 THWN-2 IN 1-1/4" PVC40, ~25'
TO AUX. POWER

PANELBOARD,
SEE SHEET WP602.3
SEL-735

PV METER

TO GELI EMS,
SEE SHEET WP601.4
(1) CAT5E/6 IN 1"
PVC40 ~25' (DATA)

TO ALSOENERGY DAS,
SEE SHEET WP602.2
RS-485 TWISTED PAIR IN
1" PVC40 ~725' (DATA)
M
SEL-735

BESS METER

TO GELI EMS,
SEE SHEET WP601.4
(1) CAT5E/6 IN 1" PVC40 ~30' (DATA)
5 STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024

SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET

KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765
ELECTRICAL 3LD
WP602.4
ELECTRICAL 3LD
WP602.4
Scale: NTS
ELECTRICAL 3LD - PV & BESS SWITCHGEARA1

GENERAL SHEET NOTES

SHEET KEYNOTES

WIRE LEGEND
CONDUCTOR 277/480V, 3PH, 4W 120/208V, 3PH, 4W 120/240V, 3PH, 3W AC ɸ1 BROWN BLACK BLACK
AC ɸ2 ORANGE/PURPLE RED ORANGE
AC ɸ3 YELLOW BLUE BLUE

AC NEUTRAL GRAY WHITE WHITE

DC POSITIVE RED RED RED

DC NEGATIVE BLACK BLACK BLACK

GROUND GREEN GREEN GREEN
NOTE: AC WIRE INSULATION COLORS SHALL MATCH THE EXISTING BUILDING(S) AND COMPLY WITH THE LATEST VERSION OF THE CEC ELECTRICAL CODE.

1. EQUIPMENT SHALL BE INSTALLED AND LABELED IN

ACCORDANCE WITH THE CEC AND ALL APPLICABLE

REQUIREMENTS OF THE SERVING UTILITY COMPANY AND
LOCAL AUTHORITY HAVING JURISDICTION (AHJ).

2. DISCONNECTS MUST COMPLY WITH CEC 690.15 AND PROVIDE
WARNING SIGN PER CEC 690.13. FUSED DISCONNECT SWITCH
TO HAVE GROUND FAULT PROTECTION PER CEC 230.95 AND
ARC ENERGY REDUCTION PER CEC 240.67.

3. LISTING AGENCY NAMES AND NUMBERS TO BE INDICATED ON
POWER INVERTER AND SOLAR MODULES PER CEC 110.3(B).

4. LABELED "PHOTOVOLTAIC SYSTEM AC COMBINER."

5. UTILITY METER LABELED "PHOTOVOLTAIC SYSTEM
MONITOR.” CT COMPARTMENT PER EUSERC 322, 330. METER
DOOR PER EUSERC 333. METER SOCKET IS 15J.

6. LABELED “PHOTOVOLTAIC SYSTEM UTILITY DISCONNECT”

SWITCH TO BE VISUAL OPEN AND ACCESSIBLE AND
CONFORM TO CEC 705.22.

7. LABELED “WARNING: THIS PANEL SUPPLIED BY MULTIPLE
SOURCES OF POWER: 1. UTILITY POWER, 2. PHOTOVOLTAIC
SYSTEM - DISCONNECT ALL SOURCES BEFORE SERVICING.”

8. POINT OF INTERCONNECTION SHALL BE IN ACCORDANCE
WITH CEC 705.11. SOLAR-READY BREAKER TO HAVE GROUND
FAULT PROTECTION PER CEC 215.10 AND ARC ENERGY
REDUCTION PER CEC 240.87.

9. PROVIDE IDENTIFICATION ALONG WITH POSITIVE & NEGATIVE CONDUCTORS PER CEC 210.5(C)(2).

10. MINIMUM BENDING RADIUS OF PHOTOVOLTAIC MODULE

LEADS SHALL CONFORM WITH MINIMUM BENDING RADIUS

SET FORTH BY THE MODULE MANUFACTURER OR ARTICLE
338.24, WHICHEVER IS MORE STRINGENT.

11. MINIMUM CONNECTORS FOR PV SOURCE CIRCUITS, PV

JUMPER CABLES, AND MODULE LEVEL POWER ELECTRONICS

TO BE LISTED AND IDENTIFIED FOR INTERMATABILITY, AS
DESCRIBED IN MANUFACTURER'S INSTRUCTIONS. MATING

CONNECTORS THAT ARE NOT LISTED ARE NOT TO BE
UTILIZED FOR PROJECT.

12. AC POWER CONDUITS TO CONVEY (3) CURRENT CARRYING
CONDUCTORS AND AN EGC. NO NEUTRAL REQUIRED.

13. ALL INVERTERS ARE TO HAVE THE MAX 250kW AC OUTPUT
OPTION SELECTED. REFER TO INVERTER DATA SHEET ON
WK801.

1. CONDUIT ABOVE GRADE SHALL BE EMT. ALL CONDUIT BELOW
GRADE SHALL BE PVC OR HDPE WITH RMC RISER. USE
SCHEDULE 40 FOR BELOW GRADE CONDUIT RUN UNDER
GRASSY AREAS.

2. ALL COPPER (CU) CONDUCTORS IN CONDUIT SHALL BE
THWN-2 OR XLPE. ALL EXPOSED CONDUCTORS SHALL BE
PVWIRE. ALL ALUMINUM (AL) CONDUCTORS IN CONDUIT
SHALL BE XHHW-2, OR XLPE.

3. ALUMINUM CONDUCTORS SHALL BE BRUSHED AND TREATED
WITH ANTIOXIDANT COMPOUND AT TERMINAL POINTS.

4. TORQUE: ALL CONDUCTORS LANDING IN SCREW

CONNECTIONS MUST BE PROPERLY TIGHTENED TO THE
MANUFACTURER'S TORQUE REQUIREMENTS. ALL BOLTED

CONDUCTOR TERMINATIONS MUST BE TORQUED TO THEIR
RATED VALUE. IT IS THE SUBCONTRACTOR'S

RESPONSIBILITY TO ENSURE ALL CONDUCTORS WITH

TORQUE REQUIREMENTS HAVE BEEN MARKED WITH A PAINT

PEN OR PERMANENT MARKER

AT THE TIME THAT THE
TORQUE TEST WAS DONE.

5. SOLAR ENERGY PRODUCTION MONITORING SHALL BE
INSTALLED AT PV & BESS SWITCHGEAR.

6. IMPACT DRIVERS ARE NOT APPROVED FOR USE ON
INVERTERS OR WIRE BOXES.

7. THE BESS WILL BE CONFIGURED TO ENSURE IT IS 100%

CHARGED FROM THE SOLAR PV SYSTEM WITH NO CHARGING
FROM THE UTILITY GRID. THIS WILL BE ACCOMPLISHED WITH

THE GELI ENERGY MANAGEMENT SYSTEM AND THE TESLA
SITE CONTROLLER SERVING AS A POWER CONTROL SYSTEM.

PROFESSIO
NA

L ENGINEER
E19765
TO

EXISTING
LOADS

TO UTILITY

TRANSFORMER
M
8 MSB
7 TO

EXISTING
LOADS
MTS
2500AF
2000AT
3P
480VAC, 3PH, 4W
4000A BUS, 4000A MAIN (EXST)
4000AF
4000AT
3P

EXISTING

PG&E METER
3000AF
3000AT
3P
LSIG

INTERCONNECTION
- 3000A, 480VAC, 3ɸ
- LINE-SIDE

CONNECTION VIA

SOLAR READY

BREAKER SECTION
- PER CEC 705.11

MAIN BREAKER FOR

OVERALL SITE

SERVICE
TO EXISTING 1250kW

GENERATOR

PV UTILITY DISCONNECT

EATON PRINGLE BOLTED PRESSURE
SWITCH CB-30-3-4-B-120-480-G, OAE
480V, 3000A FUSIBLE W/ 3000A FUSES,
NEMA 3R, 3P, 4W, VIEWABLE, LOCKABLE,

PAD MOUNTED
2256.3A
P
ACD.01
3000A FUSIBLE W/
3000A FUSES

BOLTED PRESSURE
SWITCH

ARC ENERGY

REDUCTION
PER CEC 240.67
GFP PER CEC 230.95
(WITH VIEWING

WINDOW)
ɸ1 ɸ2 ɸ3 N G
62 TO SWGR.01,

REFER TO
SHEET WP602.4
2256.3A
N
M
SEL-735

NEW OVERALL SITE

METER FOR BESS
CONTROLLER (3) CT TWISTED PAIR IN
3/4" EMT, APPROX. 20'
M
SEL-735

OVERALL OUTPUT
METER(3) CT TWISTED PAIR IN
3/4" PVC40, APPROX. 20'

TO GELI EMS
REFER TO SHEET WP602.3
(2) CAT5E/6 IN 1" PVC40 ~275' (DATA)
(1) CAT5E/6 IN 1" EMT ~5' (DATA)
STAMP:

CITY OF FAIRFIELD

WATERMAN TREATMENT PLANT SOLAR PROJECT
1785.0 kW DC STC RATING
2900 VISTA GRANDE CIRCLE
FAIRFIELD, CA 95434
12 3 4 56
E
D
C
B
A
12 3 4 56
E
D
C
B
A

PERMITTING SET
HoltRenewables, 2025

AS NOTED
ANSI D - 22X34
J
H
G
F
E
D 08/13/2025
C 05/05/2025
B 11/22/2024
A 07/26/2024
SLS
SLS
SLS
SLS

ISSUED FOR PERMITTING
90% SET
60% SET
30% SET
KMB
JC
EF/JMR
CH
CLIENT:

Allison D. Kimball

PROFESSIONAL ENGINEER
8/13/25CA LICENSE: E19765
ELECTRICAL 3LD
WP602.5
ELECTRICAL 3LD
WP602.5
Scale: NTS
ELECTRICAL 3LD - INTERCONNECTIONA1

GENERAL SHEET NOTES

SHEET KEYNOTES

WIRE LEGEND
CONDUCTOR 277/480V, 3PH, 4W 120/208V, 3PH, 4W 120/240V, 3PH, 3W AC ɸ1 BROWN BLACK BLACK
AC ɸ2 ORANGE/PURPLE RED ORANGE
AC ɸ3 YELLOW BLUE BLUE

AC NEUTRAL GRAY WHITE WHITE

DC POSITIVE RED RED RED

DC NEGATIVE BLACK BLACK BLACK

GROUND GREEN GREEN GREEN
NOTE: AC WIRE INSULATION COLORS SHALL MATCH THE EXISTING BUILDING(S) AND COMPLY WITH THE LATEST VERSION OF THE CEC ELECTRICAL CODE.

1. EQUIPMENT SHALL BE INSTALLED AND LABELED IN

ACCORDANCE WITH THE CEC AND ALL APPLICABLE

REQUIREMENTS OF THE SERVING UTILITY COMPANY AND
LOCAL AUTHORITY HAVING JURISDICTION (AHJ).

2. DISCONNECTS MUST COMPLY WITH CEC 690.15 AND PROVIDE
WARNING SIGN PER CEC 690.13. FUSED DISCONNECT SWITCH
TO HAVE GROUND FAULT PROTECTION PER CEC 230.95 AND
ARC ENERGY REDUCTION PER CEC 240.67.

3. LISTING AGENCY NAMES AND NUMBERS TO BE INDICATED ON
POWER INVERTER AND SOLAR MODULES PER CEC 110.3(B).

4. LABELED "PHOTOVOLTAIC SYSTEM AC COMBINER."

5. UTILITY METER LABELED "PHOTOVOLTAIC SYSTEM
MONITOR.” CT COMPARTMENT PER EUSERC 322, 330. METER
DOOR PER EUSERC 333. METER SOCKET IS 15J.

6. LABELED “PHOTOVOLTAIC SYSTEM UTILITY DISCONNECT”

SWITCH TO BE VISUAL OPEN AND ACCESSIBLE AND
CONFORM TO CEC 705.22.

7. LABELED “WARNING: THIS PANEL SUPPLIED BY MULTIPLE
SOURCES OF POWER: 1. UTILITY POWER, 2. PHOTOVOLTAIC
SYSTEM - DISCONNECT ALL SOURCES BEFORE SERVICING.”

8. POINT OF INTERCONNECTION SHALL BE IN ACCORDANCE
WITH CEC 705.11. SOLAR-READY BREAKER TO HAVE GROUND
FAULT PROTECTION PER CEC 215.10 AND ARC ENERGY
REDUCTION PER CEC 240.87.

9. PROVIDE IDENTIFICATION ALONG WITH POSITIVE & NEGATIVE CONDUCTORS PER CEC 210.5(C)(2).

10. MINIMUM BENDING RADIUS OF PHOTOVOLTAIC MODULE

LEADS SHALL CONFORM WITH MINIMUM BENDING RADIUS

SET FORTH BY THE MODULE MANUFACTURER OR ARTICLE
338.24, WHICHEVER IS MORE STRINGENT.

11. MINIMUM CONNECTORS FOR PV SOURCE CIRCUITS, PV

JUMPER CABLES, AND MODULE LEVEL POWER ELECTRONICS

TO BE LISTED AND IDENTIFIED FOR INTERMATABILITY, AS
DESCRIBED IN MANUFACTURER'S INSTRUCTIONS. MATING

CONNECTORS THAT ARE NOT LISTED ARE NOT TO BE
UTILIZED FOR PROJECT.

12. AC POWER CONDUITS TO CONVEY (3) CURRENT CARRYING
CONDUCTORS AND AN EGC. NO NEUTRAL REQUIRED.

13. ALL INVERTERS ARE TO HAVE THE MAX 250kW AC OUTPUT
OPTION SELECTED. REFER TO INVERTER DATA SHEET ON
WK801.

1. CONDUIT ABOVE GRADE SHALL BE EMT. ALL CONDUIT BELOW
GRADE SHALL BE PVC OR HDPE WITH RMC RISER. USE
SCHEDULE 40 FOR BELOW GRADE CONDUIT RUN UNDER
GRASSY AREAS.

2. ALL COPPER (CU) CONDUCTORS IN CONDUIT SHALL BE
THWN-2 OR XLPE. ALL EXPOSED CONDUCTORS SHALL BE
PVWIRE. ALL ALUMINUM (AL) CONDUCTORS IN CONDUIT
SHALL BE XHHW-2, OR XLPE.

3. ALUMINUM CONDUCTORS SHALL BE BRUSHED AND TREATED
WITH ANTIOXIDANT COMPOUND AT TERMINAL POINTS.

4. TORQUE: ALL CONDUCTORS LANDING IN SCREW

CONNECTIONS MUST BE PROPERLY TIGHTENED TO THE
MANUFACTURER'S TORQUE REQUIREMENTS. ALL BOLTED

CONDUCTOR TERMINATIONS MUST BE TORQUED TO THEIR
RATED VALUE. IT IS THE SUBCONTRACTOR'S

RESPONSIBILITY TO ENSURE ALL CONDUCTORS WITH

TORQUE REQUIREMENTS HAVE BEEN MARKED WITH A PAINT

PEN OR PERMANENT MARKER

AT THE TIME THAT THE
TORQUE TEST WAS DONE.

5. SOLAR ENERGY PRODUCTION MONITORING SHALL BE
INSTALLED AT PV & BESS SWITCHGEAR.

6. IMPACT DRIVERS ARE NOT APPROVED FOR USE ON
INVERTERS OR WIRE BOXES.

7. THE BESS WILL BE CONFIGURED TO ENSURE IT IS 100%

CHARGED FROM THE SOLAR PV SYSTEM WITH NO CHARGING
FROM THE UTILITY GRID. THIS WILL BE ACCOMPLISHED WITH

THE GELI ENERGY MANAGEMENT SYSTEM AND THE TESLA
SITE CONTROLLER SERVING AS A POWER CONTROL SYSTEM.

PROFESSIO
NA

L ENGINEER
E19765
ATTACHMENT 2
EXHIBIT F – General Conditions and Technical Speciﬁcations, ATTACHMENT B – Site Assessment Table
Contractor: Onyx / HOLT Under 40% ITC Scenario
Section 1: Site and System Information
Site Name Waterman Treatment Plant
Site Designator A
Service Account ID 7605929944
Meter Number 1010078883
Service Address 0
Site Address 2900 Vista Grande Circle, Fairfield, CA 95434 Solar Facility Target "Annual Production Estimate"
(kWh) 3050675
Target Battery System Size (kW) 448
Target Battery System Size (kWh) 1795

NEM-A (Y/N) N
NEM-A SAIDs N/A
Annual Meter Consumption (kWh) 3659981
Annual Ex-Solar Meter Consumption (kWh) 3659981
Meter Max Demand (kW) 768
Ex-Solar Max Demand (kW) 768
Current Rate Schedule B-19
Post Construction Rate Schedule B-19-S
Interconnection Point Rating (Volts / Amps) 480V
Distribution Utility Transformer Size (kVA) TBD
Existing Other Generation Back-up Generation
Section 2: Solar Facility
Array Structure OEM TerraSmart
Installation Type (GM, SS, RM etc.) Fixed Tilt GM
Azimuth (°) 180
Tilt (°) 20
Minimum Clearance Height (ft) 3
Solar PV Panel OEM Hanwha Qcells
Solar PV Model # QCELLS Q.PEAK DUO XL-G11S
Solar PV Panel Rating (W) 595
Solar PV Panel Quantity (#) 3010
Solar PV Panels Per String (#) 120 Strings of 25 Modules Solar Facility Capacity (kWSTC-DC) 1,785.00
Inverter OEM Chint Power
Inverter Model # Chint SCH275KLT-DO/US-800-36 250W AC output Inverter Quantity 5
Total Inverter Capacity (kW-AC) 250.00
DC/AC Ratio 7.14
AC Inverter voltage (V) 800
Solar Facility Transformer Size (kVA) 1500
Year 1 "Annual Production Estimate" (kWh) 3,053,635
Solar PV Production Annual Degradation (%) 0.5%
Percentage of Year 1 Annual Production Estimate to Target "Annual Production Estimate" 1.000970343 Section 3: Battery System
Battery System Size (kWh) 1,795.0
Battery System Inverter Size (kW-AC) 448.0
Duration (hrs.) 4.0
Battery OEM Tesla
Battery System Inverter OEM Tesla
Battery System Round Trip Efficiency (%) 86.00%
Additional System De-rate (%) 2.00%
Anticipated Annual Full Discharges (Yr. 1 #) 356
Battery System Transformer Size (kVA) 200 / 250
Capable of Exporting for NEM Credits (Y/N) N/A
Battery System Warranty Term (YRS) 15.00
Section 4: EVCS
# of Future L1 EV Chargers Planned N/A
# of Future L2 EV Chargers Planned N/A
# of Conduits Needed for Future Installation of L1 EV Chargers N/A # of Conduits Needed for Future Installation of L2 EV Chargers N/A Section 5: System Offer Costs
Total "Development Costs" included in "Power Price" ($) 385,000.00$ Anticipated ADA Upgrade Costs Included in "Power Price" ($) -$ Anticipated ADA Upgrade Costs Included in "Contract Sum" ($) -$ Anticipated Site Electrical System Upgrade Costs included in "Power Price" ($) -$ Anticipated Site Electrical System Upgrade Costs Included in "Contract Sum" ($) -$ Anticipated Distribution Utility Upgrade Costs included in "Power Price" ($) 4,000.00$ Anticipated Distribution Utility Upgrade Costs ($) 4,000.00$ Change to "Power Price" per $10,000 change in Distribution Upgrade Costs ($/kWh) 0.0005$ Incentive Amount ($) N/A
Incentive Program N/A
ITC Percentage (%) 40%
Solar Facility Cost ($) Bundled in PPA
Battery System Cost ($) Bundled in PPA
PPA Term (YRS) 25
Solar Facility "Power Price" ($/kWh) - 40% ITC Scenario 0.1210$ Solar Facility "Power Price" Annual Escalator (%) 0.0%
"Battery System Services Rate" ($/month) N/A
"Battery System Services Rate" Annual Escalator (%) 0.0% System "Termination Value" (Yr 1 $) 11,300,685$
System "Termination Value" (Yr 6 $) 4,812,914$
Increase to Solar Facility "Power Price" due to XXX ($/kWh) N/A Incremental Cost for Solar Facility Extended Inverter Warranty ($) N/A Incremental Cost to use all Copper Wiring ($) N/A
Incremental Cost to add Backup Power Solution ($) N/A
Incremental Cost to add XXXXX ($) N/A
Section 6: Utility Billing (assume 0% escalation for rates) YR 0 Existing Utility Bill ($) $10,864,161
YR 0 Existing Utility Bill Demand Charges ($) $423,265
YR 0 Existing Utility Bill Energy Charges ($) $604,907
YR 1 Total Utility Bill ($) Please reference Savings Analysis Report Utility Bill Energy Charges Post-Solar PV ($) Please reference Savings Analysis Report Utility Bill Demand Charges Post-Solar PV ($) Please reference Savings Analysis Report Utility Bill Energy Charges Post-Battery System ($) Please reference Savings Analysis Report Utility Bill Demand Charges Post-Battery System ($) Please reference Savings Analysis Report YR 1 Utility Bill Demand Charge Savings ($) Please reference Savings Analysis Report YR 1 Utility Bill Energy Savings ($) Please reference Savings Analysis Report YR 1 Total Utility Bill Savings ($) Please reference Savings Analysis Report Section 7: Other Cost Savings (assume 0% escalation for rates) Demand Response Revenue (YR 1 $) Please reference Savings Analysis Report Other
Section 8: Performance Guarantee Under NEM 2.0
Solar Facility "Output Guarantee Rate" (YR 1 $/kWh) 0.027 Solar Facility Output Guarantee Rate (YR 1 $/kWh) 0.027 Solar Facility "Output Guarantee Rate" Annual Escalation (%) 0.0% Solar Facility Output Guarantee Rate" Annual Escalation (%) Solar Facility "Output Guarantee" (YR 1 kWh) 0
Solar Facility Output Guarantee (YR 1 kWh) 0
"Battery System Guarantee Rate" ($/hr) $40/Cycle
Battery System Guarantee Rate (INSERT UNITS) $40/Cycle
"Battery System Guarantee Rate" Annual Escalation (%) 0.0% Battery System Guarantee Rate Annual Escalation (%) 0.0% Battery System "Guaranteed Cycles" (YR 1 #) 320
Battery System Guaranteed Cycles (YR 1 #) 320
Battery System "Guaranteed Cycles" Annual Change (%) See Tesla Spec Sheet for degredation curve Battery System Guaranteed Cycles Annual Change (%) See Tesla Spec Sheet for degredation curve "Battery System Guarantee" (YR 1 kWh) 1615.5
Battery System Guarantee Cost ($)
ATTACHMENT 3
EXHIBIT F – General Conditions and Technical Speciﬁcations, ATTACHMENT C – Project Schedule
ID Task
Mode
Task Name Duration Start Finish Predecessors Successors % Complete Resource Names 1 City of Fairfield 1785.0 kW DC Fixed-Tilt Ground Mount Milestones 1682 days Thu 12/5/19 Fri 6/5/26 0% 34 City of Fairfield 1785.0 kW DC Fixed-Tilt Ground Mount 666 days Wed 11/8/23 Fri 6/5/26 0% 35 Contract 123 days Wed 11/8/23 Mon 4/29/24 0%
36 Proposal Submission 1 day Wed 11/8/23 Wed 11/8/23 37 0% 37 Contract Execution 105 days Thu 11/30/23 Wed 4/24/24 36 2 0% 38 Engineering Notice to Proceed 0 days Mon 4/29/24 Mon 4/29/24 3,49,42 0% 39 Pre-Construction 469 days Mon 4/29/24 Fri 2/20/26 0% 40 Design & Engineering 317 days Mon 4/29/24 Tue 7/22/25 11 0% 41 Site Prep/Analysis 242 days Mon 4/29/24 Fri 4/4/25 45,46,47,58 0% 42 Environmental Studies 65 days Mon 4/29/24 Tue 7/30/24 38 5,43FS+4 days0% Onyx 43 Geotech study and report 173 days Tue 8/6/24 Fri 4/4/25 42FS+4 days 4 0% 44 Civil engineering (grading, roads, drainage, SWPPP) 15 days Mon 4/7/25 Fri 4/25/25 0% 45 Topo Report 15 days Mon 4/7/25 Fri 4/25/25 41 0%
46 SWPP Reports/Anyalsis 15 days Mon 4/7/25 Fri 4/25/25 41 6 0% 47 Grading, Roads, Equipment pads 15 days Mon 4/7/25 Fri 4/25/25 41 0% 48 Electrical Design 274 days Mon 4/29/24 Tue 5/20/25 0% 49 60% Design Drawings due to Site Host 25 days Mon 4/29/24 Mon 6/3/24 38 50,4 0% 50 60% Drawings Site Host Review 5 days Tue 6/4/24 Mon 6/10/24 49 51,5 0% 51 90% Design Drawings due to Site Host 205 days Tue 6/11/24 Wed 3/26/25 50 52,6,53 0% 52 90% Drawings Site Host Review 10 days Thu 3/27/25 Wed 4/9/25 51 54,7,78FS+10 days,74,75,76,77,79,80,820% 53 Execution of Holt/Onyx Contract 10 days Thu 3/27/25 Wed 4/9/25 51 54 0% 54 100% Design Drawings due to Site Host 14 days Thu 4/10/25 Tue 4/29/25 52,53 55,8 0% 55 100% drawings Site Host Review 10 days Wed 4/30/25 Tue 5/13/25 54 56,9 0% 56 IFC Stamped Drawings 5 days Wed 5/14/25 Tue 5/20/25 55 10,67 0% 57 Structural Design 75 days Mon 4/7/25 Tue 7/22/25 0%
58 50% Design Drawings due to Site Host 15 days Mon 4/7/25 Fri 4/25/25 41 59,5 0% 59 50% Drawings Site Host Review 10 days Mon 4/28/25 Fri 5/9/25 58 60,6 0% 60 90% Design Drawings 15 days Mon 5/12/25 Mon 6/2/25 59 61,7 0% 61 90% Drawings Site Host Review 10 days Tue 6/3/25 Mon 6/16/25 60 62,8 0% 62 100% Design Drawings due to Site Host 10 days Tue 6/17/25 Mon 6/30/25 61 63,9 0% 63 100% drawings Site Host Review 10 days Tue 7/1/25 Tue 7/15/25 62 64,10,65 0% 64 IFC Stamped Drawings 5 days Wed 7/16/25 Tue 7/22/25 63 0% 65 Procurement & Pemiting Notice to Proceed 0 days Tue 7/15/25 Tue 7/15/25 63 69,70,71 0% 66 Permits & Interconnection 98 days Wed 5/21/25 Wed 10/8/25 13 0% 67 Utility Interconnection Application and Initial Review 70 days Wed 5/21/25 Thu 8/28/25 56 12,81 0% 68 AHJ Permitting and Approvals 60 days Wed 7/16/25 Wed 10/8/25 0% 69 Site Permit 60 days Wed 7/16/25 Wed 10/8/25 65 0%
70 Building Permit 60 days Wed 7/16/25 Wed 10/8/25 65 0% 71 Electrical Permit 60 days Wed 7/16/25 Wed 10/8/25 65 121FS+30 days,830% 72 Procurement Major Equipment Ordered (After Approved Submittal) 224 days Thu 4/10/25 Fri 2/20/26 15,14SS 0% 73 Solar Modules Provided by Onyx 50 days Wed 8/13/25 Wed 10/22/25 83SS-40 days 0% Onyx 74 Inverters 40 days Thu 4/10/25 Thu 6/5/25 52 17 0%
75 Racking 45 days Thu 4/10/25 Thu 6/12/25 52 92,16,85FS+30days0% 76 AC COMBINER 100 days Thu 4/10/25 Fri 8/29/25 52 0%
77 PV SWITCHGEAR 25 wks Thu 4/10/25 Mon 10/6/25 52 19 0% 78 Telsa Battery provided by Onyx 150 days Thu 4/24/25 Mon 11/24/25 52FS+10 days 109FS+10 days0% Onyx 79 PV TRANSFORMER 25 wks Thu 4/10/25 Mon 10/6/25 52 18 0% 80 PV & BESS SWITCHGEAR 30 wks Thu 4/10/25 Mon 11/10/25 52 108FS+5 days,1010% 81 PV UTILITY DISCONNECT 25 wks Fri 8/29/25 Fri 2/20/26 67 107FS+5 days0% 82 Data MONITORING System "DAS" 40 days Thu 4/10/25 Thu 6/5/25 52 20 0% 83 Construction Notice to Proceed (Permit Approved) 1 day Wed 9/17/25 Wed 9/17/25 71 86,73SS-40 days0% 84 Construction 149 days Wed 9/17/25 Tue 4/21/26 23SS 0% 85 Site Preparation 149 days Wed 9/17/25 Tue 4/21/26 75FS+30 days 22,21SS 0% 86 SWPPP 3 days Wed 9/17/25 Mon 9/22/25 83 87,90 0%
87 Temp Fencing 5 days Mon 9/22/25 Mon 9/22/25 86 88 0% 88 Tree Removal 5 days Wed 10/22/25 Tue 10/28/25 87 102 0% 89 Mechanical Installation 38 days Wed 10/15/25 Fri 12/5/25 24 0% 90 Survey and Layout 3 days Wed 10/15/25 Fri 10/17/25 86 91 0%

Page 1 ends

ID Task
Mode
Task Name Duration Start Finish Predecessors Successors % Complete Resource Names 91 Install Piles 15 days Mon 10/20/25 Fri 11/7/25 90 92SS+5 days 0% 92 Install Racking 20 days Mon 10/27/25 Fri 11/21/25 75,91SS+5 days 93SS+5 days 0% 93 Install Modules 20 days Mon 11/3/25 Fri 11/28/25 92SS+5 days 94 0% 94 Mechanical QA/QC Final Inspections 5 days Mon 12/1/25 Fri 12/5/25 93 0% 95 Electrical Installation 125 days Wed 10/29/25 Tue 4/21/26 25 0% 96 DC Equipment 17 days Wed 12/3/25 Thu 12/25/25 0%
97 Inverter 7 days Wed 12/3/25 Thu 12/11/25 103 98 0%
98 DC Wiring Modules to Inverters 10 days Fri 12/12/25 Thu 12/25/25 97 0% 99 Electrical QA/QC Final Inspections 10 days Wed 4/8/26 Tue 4/21/26 100 0% 100 AC Equiqment 115 days Wed 10/29/25 Tue 4/7/26 99 0% 101 High Lift Project Deadline 1 day Mon 3/30/26 Mon 3/30/26 0% 102 Boring Trenching Underground Conduit (Work Near Facility) 15 days Wed 10/29/25 Tue 11/18/25 88 103,105FS-5 days,106FS-5days,104FS-5days0% 103 Equitment Pad & Racks & Bollards (Work Near Facility) 10 days Wed 11/19/25 Tue 12/2/25 102 97 0% 104 AC COMBINER 7 days Wed 11/12/25 Thu 11/20/25 102FS-5 days 0% 105 PV SWITCHGEAR (Work Near Facility) 10 days Wed 11/12/25 Tue 11/25/25 102FS-5 days 0% 106 PV TRANSFORMER (Work Near Facility) 10 days Wed 11/12/25 Tue 11/25/25 102FS-5 days 0% 107 PV UTILITY DISCONNECT (Work Near Facility) 10 days Mon 3/2/26 Fri 3/13/26 81FS+5 days 111FS+2 days,110FS+2days0% 108 PV & BESS SWITCHGEAR (Work Near Facility) 10 days Tue 11/18/25 Mon 12/1/25 80FS+5 days 0% 109 Tesla Battery (Work Near Facility) 15 days Tue 12/9/25 Mon 12/29/25 78FS+10 days 112FS+13 days0% 110 AC Wiring Installation 15 days Wed 3/18/26 Tue 4/7/26 107FS+2 days 0% 111 MV Wire Installation (Work Near Facility) 15 days Wed 3/18/26 Tue 4/7/26 107FS+2 days 115FS-15 days0% 112 BESS Wire Installation (Work Near Facility) 15 days Fri 1/16/26 Thu 2/5/26 109FS+13 days 113 0% 113 DAS equipment 4 days Fri 2/6/26 Wed 2/11/26 112 114 0% 114 DAS Wiring 6 days Thu 2/12/26 Thu 2/19/26 113 0%
115 INTERCONNECTION (Work Near Facility) 1 day Wed 3/18/26 Wed 3/18/26 111FS-15 days 26,117,116FS+15days0% 116 PV Mechanical Completion 1 day Thu 4/9/26 Thu 4/9/26 115FS+15 days 27,118,119 0% 117 AHJ & Utility Inspections 18 days Thu 3/19/26 Mon 4/13/26 115 0% 118 Building Inspection 2 days Fri 4/10/26 Mon 4/13/26 116 0% 119 Electrical Inspection 2 days Fri 4/10/26 Mon 4/13/26 116 122 0% 120 Submission of Final Electrical Clearance to PG&E 1 day Mon 4/13/26 Mon 4/13/26 0% 121 Submit PPI Docs to PG&E (BESS Requirement) 70 days Thu 11/20/25 Wed 2/25/26 71FS+30 days 0% 122 Utility Inspection/Permission to Operate (PTO) 9 days Tue 4/14/26 Fri 4/24/26 119 29,124,125,1260% 123 Testing & Commissioning 10 days Mon 4/27/26 Fri 5/8/26 129FS+1 day,30,1270% 124 DC Commissioning 10 days Mon 4/27/26 Fri 5/8/26 122 0% 125 AC Gear Commissioning 10 days Mon 4/27/26 Fri 5/8/26 122 0% 126 DAS Commissioning 10 days Mon 4/27/26 Fri 5/8/26 122 0% 127 Commercial Operation Date 1 day Mon 5/11/26 Mon 5/11/26 123 31 0% 128 Post-Construction (Close Out) 17 days Tue 5/12/26 Thu 6/4/26 135 0% 129 Project Walkthrough/ Punchlist 2 days Tue 5/12/26 Wed 5/13/26 123FS+1 day 130,131,132,133,1340% 130 Prepare As Built Plans 15 days Thu 5/14/26 Thu 6/4/26 129 0% 131 Deliver O&M Manuals 15 days Thu 5/14/26 Thu 6/4/26 129 0% 132 Owner/Operator Training 15 days Thu 5/14/26 Thu 6/4/26 129 0% 133 Punch List Signoff 15 days Thu 5/14/26 Thu 6/4/26 129 0% 134 Deliver Final Submittals 15 days Thu 5/14/26 Thu 6/4/26 129 0% 135 Final Completion 1 day Fri 6/5/26 Fri 6/5/26 128 33 0%

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ATTACHMENT 4
EXHIBIT F – General Conditions and Technical Speciﬁcations, ATTACHMENT D – Commissioning Schedule
ID Task
Mode
Task Name Duration Start Finish Predecessors Successors % Complete Resource Names 1 City of Fairfield 1785.0 kW DC Fixed-Tilt Ground Mount Milestones 1682 days Thu 12/5/19 Fri 6/5/26 0% 34 City of Fairfield 1785.0 kW DC Fixed-Tilt Ground Mount 666 days Wed 11/8/23 Fri 6/5/26 0% 35 Contract 123 days Wed 11/8/23 Mon 4/29/24 0%
36 Proposal Submission 1 day Wed 11/8/23 Wed 11/8/23 37 0% 37 Contract Execution 105 days Thu 11/30/23 Wed 4/24/24 36 2 0% 38 Engineering Notice to Proceed 0 days Mon 4/29/24 Mon 4/29/24 3,49,42 0% 39 Pre-Construction 469 days Mon 4/29/24 Fri 2/20/26 0% 40 Design & Engineering 317 days Mon 4/29/24 Tue 7/22/25 11 0% 41 Site Prep/Analysis 242 days Mon 4/29/24 Fri 4/4/25 45,46,47,58 0% 42 Environmental Studies 65 days Mon 4/29/24 Tue 7/30/24 38 5,43FS+4 days0% Onyx 43 Geotech study and report 173 days Tue 8/6/24 Fri 4/4/25 42FS+4 days 4 0% 44 Civil engineering (grading, roads, drainage, SWPPP) 15 days Mon 4/7/25 Fri 4/25/25 0% 45 Topo Report 15 days Mon 4/7/25 Fri 4/25/25 41 0%
46 SWPP Reports/Anyalsis 15 days Mon 4/7/25 Fri 4/25/25 41 6 0% 47 Grading, Roads, Equipment pads 15 days Mon 4/7/25 Fri 4/25/25 41 0% 48 Electrical Design 274 days Mon 4/29/24 Tue 5/20/25 0% 49 60% Design Drawings due to Site Host 25 days Mon 4/29/24 Mon 6/3/24 38 50,4 0% 50 60% Drawings Site Host Review 5 days Tue 6/4/24 Mon 6/10/24 49 51,5 0% 51 90% Design Drawings due to Site Host 205 days Tue 6/11/24 Wed 3/26/25 50 52,6,53 0% 52 90% Drawings Site Host Review 10 days Thu 3/27/25 Wed 4/9/25 51 54,7,78FS+10 days,74,75,76,77,79,80,820% 53 Execution of Holt/Onyx Contract 10 days Thu 3/27/25 Wed 4/9/25 51 54 0% 54 100% Design Drawings due to Site Host 14 days Thu 4/10/25 Tue 4/29/25 52,53 55,8 0% 55 100% drawings Site Host Review 10 days Wed 4/30/25 Tue 5/13/25 54 56,9 0% 56 IFC Stamped Drawings 5 days Wed 5/14/25 Tue 5/20/25 55 10,67 0% 57 Structural Design 75 days Mon 4/7/25 Tue 7/22/25 0%
58 50% Design Drawings due to Site Host 15 days Mon 4/7/25 Fri 4/25/25 41 59,5 0% 59 50% Drawings Site Host Review 10 days Mon 4/28/25 Fri 5/9/25 58 60,6 0% 60 90% Design Drawings 15 days Mon 5/12/25 Mon 6/2/25 59 61,7 0% 61 90% Drawings Site Host Review 10 days Tue 6/3/25 Mon 6/16/25 60 62,8 0% 62 100% Design Drawings due to Site Host 10 days Tue 6/17/25 Mon 6/30/25 61 63,9 0% 63 100% drawings Site Host Review 10 days Tue 7/1/25 Tue 7/15/25 62 64,10,65 0% 64 IFC Stamped Drawings 5 days Wed 7/16/25 Tue 7/22/25 63 0% 65 Procurement & Pemiting Notice to Proceed 0 days Tue 7/15/25 Tue 7/15/25 63 69,70,71 0% 66 Permits & Interconnection 98 days Wed 5/21/25 Wed 10/8/25 13 0% 67 Utility Interconnection Application and Initial Review 70 days Wed 5/21/25 Thu 8/28/25 56 12,81 0% 68 AHJ Permitting and Approvals 60 days Wed 7/16/25 Wed 10/8/25 0% 69 Site Permit 60 days Wed 7/16/25 Wed 10/8/25 65 0%
70 Building Permit 60 days Wed 7/16/25 Wed 10/8/25 65 0% 71 Electrical Permit 60 days Wed 7/16/25 Wed 10/8/25 65 121FS+30 days,830% 72 Procurement Major Equipment Ordered (After Approved Submittal) 224 days Thu 4/10/25 Fri 2/20/26 15,14SS 0% 73 Solar Modules Provided by Onyx 50 days Wed 8/13/25 Wed 10/22/25 83SS-40 days 0% Onyx 74 Inverters 40 days Thu 4/10/25 Thu 6/5/25 52 17 0%
75 Racking 45 days Thu 4/10/25 Thu 6/12/25 52 92,16,85FS+30days0% 76 AC COMBINER 100 days Thu 4/10/25 Fri 8/29/25 52 0%
77 PV SWITCHGEAR 25 wks Thu 4/10/25 Mon 10/6/25 52 19 0% 78 Telsa Battery provided by Onyx 150 days Thu 4/24/25 Mon 11/24/25 52FS+10 days 109FS+10 days0% Onyx 79 PV TRANSFORMER 25 wks Thu 4/10/25 Mon 10/6/25 52 18 0% 80 PV & BESS SWITCHGEAR 30 wks Thu 4/10/25 Mon 11/10/25 52 108FS+5 days,1010% 81 PV UTILITY DISCONNECT 25 wks Fri 8/29/25 Fri 2/20/26 67 107FS+5 days0% 82 Data MONITORING System "DAS" 40 days Thu 4/10/25 Thu 6/5/25 52 20 0% 83 Construction Notice to Proceed (Permit Approved) 1 day Wed 9/17/25 Wed 9/17/25 71 86,73SS-40 days0% 84 Construction 149 days Wed 9/17/25 Tue 4/21/26 23SS 0% 85 Site Preparation 149 days Wed 9/17/25 Tue 4/21/26 75FS+30 days 22,21SS 0% 86 SWPPP 3 days Wed 9/17/25 Mon 9/22/25 83 87,90 0%
87 Temp Fencing 5 days Mon 9/22/25 Mon 9/22/25 86 88 0% 88 Tree Removal 5 days Wed 10/22/25 Tue 10/28/25 87 102 0% 89 Mechanical Installation 38 days Wed 10/15/25 Fri 12/5/25 24 0% 90 Survey and Layout 3 days Wed 10/15/25 Fri 10/17/25 86 91 0%

Page 1 ends

Page 2 ends

ATTACHMENT 5
EXHIBIT F – General Conditions and Technical Speciﬁcations, ATTACHMENT F – Major Equipment
DAS System Hardware
Overview
AlsoEnergy wants to make it as easy as possible for you to plan and install your monitoring system hardware. That’s why we provide your core hardware devices conveniently mounted and pre-wired in a weatherproof enclosure.

DAS Assembly
• Complete with all necessary DAS
system hardware
• Preconﬁ gured for plug-and-play
capability with the PowerTrack
Platform
• Hardware mounted and pre-wired
• NEMA 4 rated enclosures for exterior
mounting
• Indoor mounting hardware included
• Built to your speciﬁ cations
• ETL listed
End-to-end DAS systems from AlsoEnergy
are tested, conﬁ gured, assembled, and wired
in our ETL listed facility in Boulder, CO.

Hardware Components
AlsoEnergy Data Logger
Pre-conﬁ gured for use with PowerTrack
Accepts data from RS-485, RS-232, or
Ethernet connected devices.

Includes internal storage capacity and a
touch screen LCD display.

Energy Meter
Get revenue grade accuracy,
as required by many clients.

Accepts single phase, split phase, and
three phase loads.

Includes LCD display.

Weather Stations and Environmental Sensors
Our high quality weather stations can accommodate any solar or wind metric requirements.

Weather stations can ﬁ t into the main monitoring communications enclosure or have their own dedicated enclosure.
• Anemometers
• Pyranometers (Hukseflux, Apogee,
Kipp and Zonen)
• Ambient temperature sensors
• Module Temperatures Sensors
• Basic and full weather station packages
• High temperature weather stations
• Remote and portable stations
Cellular Modem
• 4G network
• Low power consumption
• Remote management and conﬁ guration
• Works with most major North American cellular providers Wireless Communications
• Ethernet radio
• Suitable for outdoor mounting
• Intra site communication
• Integrated antenna
• Remote oversight

Datasheet
CHINT POWER SYSTEMS AMERICA 2023/05-MKT NA Chint Power Systems America 1380 Presidential Drive, Suite 100, Richardson, TX 75081 Tel: 855-584-7168 Mail: [email protected] Web: www.chintpowersystems.com 800 Vac 3:1 AC Combiner Solution for CPS Inverters
Internal View of AC Combiner Box
The CPS 800 Vac 3:1 AC Combiner Box is designed for CPS 250/275 kW three-phase string inverters to optimize system design, installation, and wire management. The units combine the output of (3) CPS 250/275 kW inverters allowing a cost-effective s olution f or s implifying sy stem desig ns an d mi nimizing AC wir e l osses. T his solu tion e nables s avings on labor and material costs by reducing the amount of wires needed to connect CPS string inverters to the grid.

Solutions Supplier
CPS can supply inverter and BOS e quipment fo r 1 500 V applications, which enables advantages for project lo gistics, ship ment, and wa rranty management.

Decreased Wiring Costs
Combining CPS inverters with an AC Combiner Box reduces the amount of wires needed to connect the PV system to the grid.

Optimized Design
The A C Combiner Box is designed specifically for use with CPS 250/275 k W inverters.

Technical Data
Model Name
Number of input circuits
OCPD type
Disconnect
Compatible inverter(s)
Rated voltage
Rated input current
Input conductor size
Input conduit knockout size
Rated output current
Output conductor size
Output conduit knockout size
Interrupting capacity
Disconnect rating
Output fuse rating
Dimensions (H x W x D)
Weight
Padlockable enclosure (LOTO)
Grounding busbar
Breather vent
Enclosure protection degree
Operating temperature range
Operating humidity
Operating altitude
Certifications and standards
Standard
CPS DPA03-800V/US
Yes
Warranty
2 years
UL 1741, CSA C22.2 NO.107.1-16
Removable bottom plate
Safety
Environment
0% to 95%, non-condensing
8202 ft / 2500 m (no derating)
NEMA Type 3R
-22°F to +140°F / - 30°C to +60°C (derating from +104°F / +40°C) 600 A
Removable bottom plate
Yes
Mechanical
Output Parameters
Input Parameters
3 264 lbs / 120 kg
Yes
CPS SCH275KTL-DO/US-800
300-500 kcmil CU/AL (1 or 2 sets)
55 x 36.2 x 14.75 in (1400 x 920 x 375 mm)
1000 A
65 kA
800 Vac
600 A
Fuse
Yes
600-750 kcmil CU/AL (up to 4 sets)
800 A
Datasheet
CHINT POWER SYSTEMS AMERICA 2023/01-MKT NA Chint Power Systems America 1380 Presidential Drive, Suite 100, Richardson, TX 75081 Tel: 855-584-7168 Mail: [email protected] Web: www.chintpowersystems.com In-Line Cluster Mounting Bracket
The CPS In-Line Cluster Mounting Bracket is designed to provide a simple, low-cost mounting solution for CPS 250/275 kW inverters and CPS 800 Vac 3:1 AC Combiners. (3) CPS 250/275 kW and (1) 800 Vac AC Combiner can be mounted onto piles to easily install the equipment for ground mount PV applications. This solution enables savings on labor and material costs for system designs and installation.

Key Features
CPS In-Line Cluster Mounting Bracket
Designed for CPS 250/275 kW Inverters & 800 Vac AC Combiners Easily mount (3) 250/275 kW inverters and (1) 800 Vac AC Combiner Simplifies Inverter and Combiner installation
Cost-efficient mounting solution
Includes mounting bracket for CPS 800 Vac AC Combiner
In-line design to allow efficient working space

Technical Data
Cluster Components
Item No. Component Name Quantity
1 Equipment installation vertical beam 8
2 Beam 4
3 Vertical beam 6
4 Pile connector 3
5 Pile 3 (user supplied)
Model Name
Material
Dimensions (H x W x D)
Dimensions of total Cluster Mounting Bracket including
(3) 250/275 kW Inverters + (1) 800 Vac AC Combiner
Total weight of Cluster Rack
Compatible inverters
Compatible combiner
Installation method
Standard
CPS In-Line Cluster Mounting Bracket
Mounted to 3 piles (piles not included)
Warranty
2 years
CPS DPA03-800V/US
Mechanical
264 lbs / 120 kg
CPS SCH275KT L-DO/US-800
DC51D-ZM180 steel

46.3 x 231.4 x 6.8 in (1,175 x 5,877 x 172 mm)

55.1 x 231.4 x 23.3 in (1,400 x 5,877 x 643 mm)
250/275kW V2, 1500Vdc String Inverters for North America Datasheet
CPS SCH275KTL-DO/US-800 V2
The 250/275kW high power CPS three phase string inverters are designed for ground mount applications. The units are high performance, advanced and reliable inverters designed specifically for the North American e nvironment and grid.

High
efficiencies, wide operating voltages, broad temperature ranges and NEMA Type 4X enclosure enable this inverter platform to operate at high performance across many applications. The SCH275KTL inverters include a selectable Active Power of either 250kW or 275kW (factory default) with 12 MPPTs and are available with either 36 fused PV string inputs or 24 unfused PV string inputs. The CPS FlexOM solution enables communication, controls and remote product upgrades.

Key Features
CHINT POWER SYSTEMS AMERICA 2023/10-MKT NA Chint Power Systems America 1380 Presidential Drive, Suite 100, Richardson, TX 7508 Tel: 855-584-7168 Mail: [email protected] Web: www.chintpowersystems.com ◼ Anti-PID function
◼ Reactive Power at Night function
◼ CPS FlexOM Gateway enables remote FW upgrades
◼ Integrated DC disconnect switches
◼ Protection functions for enhanced reliability and safety ◼ Selectable Max AC Active Power of 250kW or 275kW
◼ UL 1741-SA certified to CA Rule 21, including SA14-18 ◼ 12 MPPTs with 36 fused inputs or 24 unfused inputs
◼ Copper and Aluminum compatible AC connections
◼ NEMA Type 4X outdoor rated, tough tested enclosure
◼ Full power capacity up to 42°C
◼ Standard 5 year warranty with extensions to 20 years
◼ Supported comm protocols (Modbus RTU, TCP/IP , PLC, CAN) ◼ UL 1741-SB and IEEE 1547-2018 certified

Model Name CPS SCH275KTL-DO/US-800-36 V2 CPS SCH275KTL-DO/US-800 -24 V2 Max. DC Input Voltage
Operating DC Input Voltage Range
Start-up DC Input Voltage / Power
MPPT Voltage Range @ PF>0.99
1 Number of MPP Trackers 12 12
Max. PV Input Current 30A per MPPT 30A per MPPT
Max. PV Short-Circuit Current 600A, 50A per MPPT 600A, 50A per MPPT Number of DC Inputs 36 Fused Inputs, 3 per MPPT 24 Non-Fused Inputs DC Disconnection Type
DC Surge Protection
Max AC Output Power (Selectable) @ PF>0.99
Max. AC Apparent Power
Rated Output Voltage
Output Voltage Range
2 Grid Connection Type
Max. AC Output Current @800Vac
Rated Output Frequency
Output Frequency Range
2 Power Factor
Current THD @ Rated Load
Max. Fault Current Contribution (1 Cycle RMS)
Max. OCPD Rating
AC Surge Protection
Max. Efficiency
CEC Efficiency
Stand-by / Night Consumption
Enclosure Protection Degree
Cooling Method
Operating Temperature Range
3 Operating Humidity
Operating Altitude
Audible Noise
User Interface and Display
Inverter Monitoring
Site Level Monitoring
Modbus Data Mapping
Remote Diagnostics / FW Upgrade Functions
Dimensions (HxWxD)
Weight
Mounting / Installation Angle
AC Termination
DC Termination
Fused String Inputs (3 per MPPT) 6
Certifications and Standards
Selectable Grid Standard
Smart-Grid Features
Reactive Power at Night
Anti-PID function
Insulation Resistance Monitoring
Onboard Fault Oscillography
PV MPPT Current Monitoring
Residual Current Monitoring
Output Overcurrent Protection
Output Short-Circuit Protection
Output Overvoltage Protection
Standard
Extended Terms
1) See user manual for further information regarding MPPT Voltage Range when operating at non-unity PF 2) The "Output Voltage Range" and "Output Frequency Range" may differ according to the specific grid standard. 3) See user manual for further requirements regarding non-operating conditions. 4) CPS AC-PLC Kit required for AC PLC communication.

Approx. 262lbs / 119kg
Type II
Environment
System and Performance

98.5%
5W

99.0%
0 to 100%
8202ft / 2500m (no derating)
CPS FlexOM (1 per 32 inverters)
NEMA Type 4X
Modbus RS485 / PLC 4 / CAN
Variable speed cooling fans
-22°F to +140°F / -30°C to +60°C (derating from +107°F / +42°C) Display and Communication
25A fuses provided (Fuse values up to 30A acceptable)
SunSpec / CPS
Standard / (with FlexOM Gateway)
10, 15 and 20 years
Warranty
Volt-RideThru, Freq-RideThru, Ramp-Rate, Specified-PF, Volt-Var, Freq-Watt, Volt-Watt 5 Years
UL1741-SA /SB Ed. 3, CSA-22.2 NO.107.1-16, IEEE1547a-2014, IEEE1547-2018, FCC PART15 IEEE 1547a-2014, IEEE 1547-2018, CA Rule 21, ISO-NE

27.2 x 41.3 x 15.7in (690 x 1050 x 400mm)
Vertical installation
Safety
Stud Type Terminal (Wire range: 4/0AWG – 750kcmil AL/CU, lugs not supplied) 36 Fused Input: Screw Clamp Fuse Holder (Wire range: #14 - # 8 AWG CU) 24 Non-Fused Input: Screw Clamp Terminal (Wire range: #14 - #8 and #6 - #4 AWG CU) 5 Mechanical
Yes
LED indicators, WiFi + APP
<80dBA @ 1m and 25°C
3-Phase / PE
704-880Vac
800Vac
215.2A
300A
<3%
>0.99 (±0.8 adjustable)
57 - 63Hz
60Hz
250kW / 275kW
275kVA
198.5A
AC Output
DC Input
500-1450Vdc
1500V
550Vdc / 500W
Load-rated DC switches
900-1300Vdc
Type II
Protection Functions
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Yes
Technical Data
5) One threaded hole per MPPT for connecting #6 - #4 AWG CU 6) Fused string inputs only applicable to the SCH275KTL 36-input model. www.terrasmart.com | [email protected]
Benefits
· Less hardware for faster installation and reduced
labor hours
· Simplified hardware featuring 2-piece bolt stacks and only two types of hardware
· Adapts to steep slopes
· Foundations for any terrain
· Included wire management
Module orientation Portrait or Landscape
Module mounting Bottom mount / Integrated electrical bonding Tilt angle 5°- 35°
Wire management Incorporated in structure – NEC compliant Configuration Portrait: up to 3 high x 12 wide / Landscape: up to 4 high x 6 wide Slopes East or West facing, up to 30% / North or South facing, up to 36% Load capacities Project specific: up to 170 MPH wind speed and 100 PSF ground snow load Foundations Ground screws / Driven piles
Warranty 20 year limited warranty
Certifications UL2703, edition 1; CPP wind tunnel tested Portrait up to 3 high x 12 wide Landscape up to 4 high x 6 wide Bifacial compatible
Specifications
GLIDE Agile
Our adjustable and durable frame features less hardware, integrated electrical bonding, and included wire management resulting in reduced labor hours. Installation times are shortened by up to 36% through simplified connections, agile parts, and seasoned field teams. Foundation consultation from an unbiased partner, based on your unique project site. No matter the terrain or weather, we’ll provide the right solution. Our versatile design enables numerous configurations allowing us to meet your unique needs and bring solar to more fields.
· Lighter, stiffer components for less freight costs
· Versatile with numerous configurations
· Durable, tolerating up to 170 MPH winds and 100 PSF
ground snow loads
· Landscape orientation is bifacial compatible to maximize potential backside power yield
Q.PEAK DUO XL-G11S.3 / BFG
Q.PEAK DUO XL-G11S
SERIES
MODEL
585-600 Wp | 156 Cells

21.5 % Maximum Module Efficiency

TOP BRAND PV

MODULES
USA
2022
The ideal solution for:

Ground-mounted
solar power plants
1 See data sheet on rear for further information.
² APT test conditions according to IEC / TS 62804-1:2015 method B (−1500 V, 168 h) including post treatment according to IEC 61215-1-1 Ed. 2.0 (CD) High-tech aluminum alloy frame protects from damage,
enables use of a wide range of mounting structures and is certified regarding IEC for high snow (5400 Pa) and wind loads (2400 Pa).

Frame for versatile mounting options
Q.ANTUM DUO technology with optimized module layout to
boost module power and improve LCOE.

Low electricity generation costs
Double glass module design enables extended lifetime with 12-year product warranty and improved 30-year performance warranty
1 .

A reliable investment
Innovative all-weather technology
Optimal yields, whatever the weather with
excellent low-light and temperature behavior.

Bifacial Q.ANTUM solar cells make efficient use of light shining on the module rear-side for radically improved LCOE.

Bifacial energy yield gain of up to 21 %
Long-term yield security with Anti LID and Anti PID
Technology
2 , Hot-Spot Protect.

Enduring high performance

Mechanical Specification

44.6 "
(1134 mm)

55.1 " (1400 mm)

96.9 " (2462 mm)

1.38 " (35 mm)
4 × Mounting slots (DETAIL A)
Frame

43.0 "
(1092 mm)
NA
Label
4 × Grounding holes,
Ø 0.18 " (4.5 mm)

15.7 " (400 mm)
8 × Mounting slots system Tracker (DETAIL B)

DET AIL A

0.63 " (16 mm)

0.33 " (8.5 mm)0.83" (21 mm)

DET AIL B

0.39 " (10 mm)

0.28" (7 mm)0.87" (22 mm)

42.9 "
(1090 mm)

31.1 " (790 mm)
≥ 13.8 " (350 mm)
≥ 29.5 " (750 mm)

20.9 " (531mm)
8 × Drainage holes

0.12 × 0.24 " (3 × 6 mm)
Tracker slot Mounting
slots
Format 96.9 in × 44.6 in × 1.38 in (including frame)
(2462 mm × 1134 mm × 35 mm)
Weight 76.9 lbs (34.9kg)
Front Cover 0.08 in (2.0 mm) thermally pre-stressed glass with anti-reflection technology
Back Cover 0.08 in (2.0 mm) semi-tempered glass
Frame Anodised aluminium
Cell 6 × 26 monocrystalline Q.ANTUM solar half cells
Junction box 2.09-3.98 × 1.26-2.36 × 0.59-0.71 in (53-101 mm × 32-60 mm × 15-18 mm), Protection class IP67, with bypass diodes
Cable 4 mm² Solar cable; (+) ≥ 29.5 in (750 mm), (−) ≥ 13.8 in (350 mm) Connector Stäubli MC4; Stäubli MC4-Evo2; - IP68
Q.PEAK DUO XL-G11S SERIES
Qcells pursues minimizing paper output in consideration of the global environment.

Note: Installation instructions must be followed. Contact our technical service for further information on approved installation of this product.

Hanwha Q CELLS America Inc. 400 Spectrum Center Drive, Suite 1400, Irvine, CA 92618, USA | TEL +1 949 748 59 96 | EMAIL [email protected] | WEB www.qcells.com Contact your Qcells Sales Representative for details regarding the module’s eligibility to be Buy American Act (BAA) compliant.

Specifications subject to technical changes © Qcells Q.PEAK_DUO_XL-G11S-BFG_series_585-600_2023-07_Rev05_NA Properties for System Design
Maximum System Voltage VSYS [V] 1500 PV module classification Class II Maximum Series Fuse Rating [A DC] 30 Fire Rating based on ANSI / UL 61730 TYPE 294 Max. Design Load, Push / Pull3 [lbs / ft2] 75 (3600 Pa) / 33 (1600 Pa) Permitted Module Temperature on Continuous Duty
−40 °F up to +185 °F
(−40 °C up to +85 °C)Max. Test Load, Push / Pull3 [lbs / ft2] 113 (5400 Pa) / 50 (2400 Pa) 3 See Installation Manual 4 New Type is similar to Type 3 but with metallic frame UL 61730, CE-compliant,
IEC 61215:2016,
IEC 61730:2016,
U.S. Patent No. 9,893,215
(solar cells)
Qualifications and Certificates
Electrical Characteristics

TEMPERATURE COEFFICIENTS
Temperature Coefficient of ISC α [% / K] +0.04 Temperature Coefficient of VOC β [% / K] −0.27 Temperature Coefficient of PMPP γ [% / K] −0.34 Nominal Module Operating Temperature NMOT [°F] 108 ± 5.4 (42 ± 3 °C)
POWER CLASS 585 590 595 600
MINIMUM PERFORMANCE AT STANDARD TEST CONDITIONS, STC1 (POWER TOLERANCE +5 W / −0 W) BSTC* BSTC* BSTC* BSTC*
Minimum
Power at MPP
1 PMPP [W] 585 639.9 590 645.4 595 650.8 600 656.3
Short Circuit Current1 ISC [A] 13.72 15.01 13.74 15.04 13.77 15.07 13.80 15.10 Open Circuit Voltage1 VOC [V] 53.57 53.76 53.60 53.79 53.63 53.82 53.66 53.85 Current at MPP IMPP [A] 13.07 14.30 13.12 14.36 13.17 14.41 13.22 14.46 Voltage at MPP VMPP [V] 44.75 44.74 44.96 44.95 45.18 45.17 45.39 45.38 Efficiency1 η [%] ≥ 21.0 ≥ 21.1 ≥ 21.3 ≥ 21.5
Bifaciality of PMPP and ISC 70 % ± 5 % • Bifaciality given for rear side irradiation on top of STC (front side) • According to IEC 60904-1-2 1 Measurement tolerances PMPP ± 3 %; ISC, VOC ± 5 % at STC: 1000 W/m²; *at BSTC: 1000 W/m² + φ × 135 W/m², φ = 70 % ± 5 %, 25 ± 2 °C, AM 1.5 according to IEC 60904-3 MINIMUM PERFORMANCE AT NORMAL OPERATING CONDITIONS, NMOT2 Minimum
Power at MPP PMPP [W] 440.5 444.2 448.0 451.8
Short Circuit Current ISC [A] 11.05 11.07 11.09 11.11
Open Circuit Voltage VOC [V] 50.67 50.69 50.72 50.75
Current at MPP IMPP [A] 10.30 10.34 10.38 10.42
Voltage at MPP VMPP [V] 42.79 42.97 43.15 43.34
1Measurement tolerances PMPP ± 3 %; ISC; VOC ± 5 % at STC: 1000 W/m2, 25 ± 2 °C, AM 1.5 according to IEC 60904-3 • ²800 W/m2, NMOT, spectrum AM 1.5 200 400 600 800 1000
90 100
80 110
10 302515 200 05

84.95 98
95 80
100
RELATIVE EFFCIENCY [%]
Qcells PERFORMANCE WARRANTY PERFORMANCE AT LOW IRRADIANCE At least 98 % of nominal power
during first year. Thereafter max.

0.45 % degradation per year. At
least 93.95 % of nominal power
up to 10 years. At least 84.95 % of
nominal power up to 30 years.

All data within measurement
tolerances. Full warranties in
accordance with the warranty
terms of the Qcells sales
organisation of your respective
country.

Typical module performance under low irradiance conditions in comparison to STC conditions (25 °C, 1000 W/m
2 ).

RELATIVE EFFCIENCY

COMPARED TO NOMINAL POWER
[%]
YEARS IRRADIANCE [W/m²]
Qcells
Industry standard of p-mono*
*Standard terms of guarantee for the 5 PV companies with the highest production capacity in 2021 (February 2021)
TESLA.COM/MEGAPACK

MECHANICAL AND MOUNTING
Ingress Ratings IP66/NEMA 3R (Main Enclosure)
IP20 (Thermal System)
Enclosure
Dimensions
+/- 13 mm (½ in)
Width: 8800 mm (346 ½ in)
Depth: 1650 mm (65 in)
Height: 2785 mm (110 in)
Maximum Weight 38,100 kg (84,000 lb)
Operating Ambient
Temperature
–30°C to 50°C (–22°F to 122°F)

REGULATORY
System is designed to be compliant to grid codes and safety standards of all major markets.

System NRTL listed to UL 1973, UL 9540, UL 9540A,
UL 1741 SB, IEC 62619, IEEE 1547
Cells NRTL listed to UL 1642

PART NUMBER
1848844-XX-Y Where X is a number between 0-9 and Y is a letter

WARRANTY
Coverage All-inclusive, equipment and energy retention
Term 15 years standard, extendable to 20 years
MEGAPACK 2 XL DATASHEET - REV. 1.8 - December 2, 2024. © Copyright Tesla, Inc, 2024 . All Rights Reserved.

POWER AND ENERGY
Megapack is configurable. Standard configurations are 2-Hour cell option C010, 4-Hour cell option C010, and 4-Hour cell option C012.

Nominal energy is specified at 25°C (77°F).

AC Power
per Megapack
Energy
per Megapack
2-Hour C010 1927 kW 3854 kWh
4-Hour C010 979 kW 3916 kWh
4-Hour C012 1042 kW 4170 kWh

ELECTRICAL
Nominal AC Voltage 480 V AC 3-phase
Nominal Frequency 50 or 60 Hz
Inverter Power
per Megapack1
2-Hour C010 Max: 2400 kVA
4-Hour C010 Max: 1320 kVA
4-Hour C012 Max: 1320 kVA
Round-Trip
Efficiency2
2-Hour C010: 91.7%
4-Hour C010: 93.7%
4-Hour C012: 91.8%
1 Scalable from 400 kVA minimum in increments of 50 kVA 2 Full-depth cycle including all power conversion and thermal system losses, at 25°C (77°F)
MEGA PACK 2 XL DATASHEET
Grid transformation for the world's largest energy projects • Best-in-class energy density and round-trip efficiency • Industry-leading power electronics and thermal system performance • Rapid and cost-effective deployment with factory-assembled and pre- tested solution
Scaled and rigorously tested product safety and reliability • Comprehensive in-house reliability testing by the leading experts in the industry
• Engineered for safety and performance at every level
• Continuous improvement based on large-scale operational experience Designed with flexibility and configurability in mind
• Modular architecture that allows for a range of configurations across multiple applications and industry-first Archetypes
• Industry experts available to identify site-specific needs • Integrated solution that allows for battery augmentation over time

CONTROLS AND COMMUNICATIONS
Protocols Modbus TCP / DNP3
Archetypes
Advanced control functions and unique design requirements based on the project's electrical topology:
• Utility Battery Only
• Utility Co-Located Plant (Battery Only)
• Utility Hybrid
• Battery Dispatch Only
• Grid-Connected Only
• Backup
• Off-Grid Microgrid
• Grid-Connected Microgrid

Exhibit J: Warranty
Tesla, Inc., 1 Tesla Road, Austin, TX 78725 email: [email protected] MEGAPACK 2 MANUFACTURER’S LIMITED WARRANTY (USA) Effective Date: December 23, 20221. What Is Covered? This Limited Warranty applies to the “Megapack System” comprised of one or more Tesla Megapack 2 battery energy storage units (each, a “Megapack”) that is supplied by Tesla, Inc. (“Tesla”) or one of our affiliates and installed in the United States of America. The agreement under which Tesla originally sold the Megapack System is the “Megapack Sales Agreement.” 1.1 Tesla warrants that the Megapack System will be free from defects in design, engineering, fabrication, manufacture or workmanship (each, a “Defect”, and “Defective” has a corollary meaning). 1.2 The batteries within the Megapack System, like all lithium-ion batteries, will experience gradual energy capacity loss with time and use. Tesla warrants that the Megapack System (but not any one or more Megapacks individually) will retain energy capacity in an amount equal to or greater than the “Minimum Energy Retention Percentage” as defined in Exhibit 1 (the “Energy Retention Warranty”). 2. Items Not Covered This Limited Warranty does not cover claims to the extent they result from any one or more of the issues listed below, except to the extent the issue was caused by a breach of a Related Contract by Tesla or its affiliate. A “Related Contract” means any agreement related to the Megapack System executed by Tesla and the original buyer or current owner of the Megapack System. 2.1 Normal wear and tear, or superficial imperfections, dents or marks that do not impact Megapack System performance; 2.2 vibration that does not impact Megapack System performance; 2.3 damage that occurs during shipping or transportation (other than shipping or transportation by or on behalf of Tesla); 2.4 any Defect that could not have been detected, prevented, limited or mitigated because Tesla couldn’t remotely access or monitor the Megapack System or data generated by the Megapack System; 2.5 any other damage or failures not caused by the manufacture of the Megapack System or its components, including damage or failures resulting from: 2.5.1 the maintenance or repair of the Megapack System by you or any third party other than Tesla or someone authorized by Tesla; 2.5.2 any failure to maintain the Megapack System in accordance with the applicable Tesla manuals; 2.5.3 failure to connect and begin use and operation of the Megapack System within the time specified in the Transportation and Storage Guidelines, or 2.5.4 the Megapack System reaching 0% state of charge and not being re-charged for more than 30 days; 2.6 failing to follow the specific instructions and recommendations regarding the use and operation of the Megapack System provided in the applicable Tesla manuals; 2.7 failing to install software updates within a reasonable time after notification by Tesla that there is an update available; or 2.8 operation of the Megapack System in a manner that violates the Energy Retention Warranty.

Tesla, Inc., 1 Tesla Road, Austin, TX 78725 email: [email protected] Additionally, you must arrange to have preventative maintenance performed by Tesla or an authorized Tesla maintenance provider. If such maintenance is not performed for more than a year, this Limited Warranty will be voided. 3. Who can make claims under this Limited Warranty? The owner of the Megapack System can make claims under this Limited Warranty. 4. When does the Limited Warranty Period begin and end? 4.1 The “Start Date” for this Limited Warranty is the earlier of (i) when Tesla issues its certificate of commissioning completion in accordance with the Megapack Sales Agreement (or if no certificate is issued, when Tesla completes commissioning); and (ii) the date falling 180 days after the date when title transfers to the original buyer under the Megapack Sales Agreement. 4.2 This Limited Warranty expires on the earlier of (i) the 15th anniversary of the Start Date, and (ii) the time when the Total Throughput (as defined in Exhibit 1) exceeds the Total Throughput Limitation indicated for Warranty Year 15. 4.3 The period between the Start Date and the expiration date set forth in Section 4.2 is the “Limited Warranty Period.” 5. What warranty applies to parts repaired or replaced under this warranty? Parts of the Megapack System repaired or replaced under this Limited Warranty are covered under this Limited Warranty until the Limited Warranty Period ends. For warranty claims specific to the Energy Retention Warranty, the replacement parts will be in a condition sufficient to achieve or exceed the minimum energy retention of the original Megapack parts, for the remainder of the Limited Warranty Period. 6. Obtaining warranty service 6.1 To obtain warranty service, you must notify Tesla of your warranty claim at the email address below within the Limited Warranty Period. When contacting Tesla, please provide proof of purchase, the Megapack serial number, original sale date and a description of the issue. For a warranty claim with respect to the Energy Retention Warranty, you must run a standard capacity test in accordance with Exhibit 1, and you must include the results of that test with your claim. 6.2 You must make the Megapack available to Tesla for inspection and service. If you make a claim under the Energy Retention Warranty, Tesla can perform one or more capacity tests in accordance with Tesla’s standard practices upon 24 hours’ prior notice. If we dispute or deny a warranty claim, we will provide our reasoning. 6.3 If you submit a valid claim under this Limited Warranty, Tesla will repair the Defective Megapack or component or replace it with an equivalent component within a reasonable time after Tesla’s validation of the claim. As part of its remedy, Tesla may elect to do any of the following in its sole discretion, among other activities: (i) repair parts (including removing such parts and reinstalling the same after repair); and/or (ii) use (A) remanufactured or refurbished parts to the extent such parts have remaining lives equivalent to the remaining life of the part replaced; or (B) equivalent or improved versions of Tesla products, features or options. Tesla will pay for disassembly of the Megapack, transportation, re-assembly and re-installation of the Megapack or components, as applicable to the warranty service. 7. Remote Monitoring In order to for Tesla to provide this Limited Warranty, Tesla requires the ability to remotely monitor the performance of the Megapack System, and provide remote firmware and software upgrades to the Megapack System. 7.1 You hereby consent to Tesla performing remote monitoring of the Megapack System at any time without further notice or consent.

Tesla, Inc., 1 Tesla Road, Austin, TX 78725 email: [email protected]

7.2 You hereby consent to Tesla’s providing such software upgrades as Tesla reasonably deems appropriate, in each case subject to your approval, provided that you may impose reasonable limitations and requirements as a condition to such approval (including, a reasonable description of the modifications made by such upgrade, reasonable assurances regarding compatibility and testing of such upgrade, and your prior agreement to the scheduling of such upgrade), among other reasonable requirements. Noncompliance with rules administered by the North American Electric Reliability Corporation and other applicable cybersecurity requirements and applicable law shall be a reasonable basis for withholding or conditioning approval. 7.3 If you withhold consent (other than as permitted in Section 7.2), impose additional requirements or fail to provide timely access for software upgrades, Tesla shall be entitled to recover its reasonable, documented, out of pocket costs arising from such withholding or additional requirements, plus 20%. 7.4 To the extent that you fail to provide Tesla with timely access to the Megapack System in accordance with this Section 7 and the Megapack System is damaged or degrades in performance as a result of such failure, you will be responsible for all resulting damage and degradation to the Megapack System and Tesla will not have any liability for such damage under this Limited Warranty or any Related Contracts. 7.5 Any information obtained by Tesla through remote monitoring of the Megapack System that falls within the parameters stated to be made available to customers in the Tesla Controls and Communication Manual, shall be owned by you. Any information obtained by Tesla through remote monitoring of the Megapack System that falls outside the parameters stated to be made available to customers in the Controls and Communication Manual shall be owned by Tesla and shall be confidential information of Tesla. Tesla shall not be required to make such information available to you. 8. Exclusive Remedies 8.1 THIS LIMITED WARRANTY IS THE ONLY EXPRESS WARRANTY MADE IN CONNECTION WITH THE MEGAPACK SYSTEM, OTHER THAN ANY EXPRESS WARRANTIES MADE TO YOU UNDER ANY RELATED CONTRACT DIRECTLY INVOLVING THE MEGAPACK SYSTEM. ALL OTHER IMPLIED OR EXPRESS WARRANTIES, INCLUDING ANY STATUTORY WARRANTY RIGHTS ARISING FROM LOCAL LAWS, ARE DISCLAIMED TO THE FULLEST EXTENT ALLOWED BY THE LAW. THE WARRANTIES TESLA DISCLAIMS INCLUDE, BUT ARE NOT LIMITED TO, IMPLIED WARRANTIES AND CONDITIONS OF MERCHANTABILITY, FITNESS FOR A PARTICULAR PURPOSE, DURABILITY, OR THOSE ARISING OUT OF A COURSE OF DEALING OR USAGE OF TRADE. 8.2 The performance of repairs and replacement by Tesla as set forth in Section 6.3 is your exclusive remedy under this Limited Warranty. Tesla does not authorize any person or entity to create for it any other obligations or liability in connection with this Limited Warranty. 9. Limitation of Liability Tesla disclaims any and all indirect, incidental, special and consequential damages arising out of or relating to Defects in the Megapack System. Tesla shall not be liable for any direct damages in excess of the original purchase price for the Megapack System. 10. Limitation on Medical Use THE MEGAPACK SYSTEM IS NOT INTENDED FOR USE AS A PRIMARY OR BACK-UP POWER SOURCE FOR LIFE-SUPPORT OR OTHER MEDICAL EQUIPMENT. TESLA DISCLAIMS ANY LIABILITY ARISING OUT OF ANY SUCH USE OF THE MEGAPACK SYSTEM. 11. Governing Law; Dispute Resolution; Venue This Limited Warranty will be governed by and interpreted under Texas law. Any dispute arising from or relating to this Limited Warranty must first be promptly referred to senior level management for resolution. If the dispute is not resolved within 20 days after referral, then you or Tesla may take such dispute to binding Tesla, Inc., 1 Tesla Road, Austin, TX 78725 email: [email protected] arbitration in accordance with the then-current Streamlined Arbitration Rules of the Judicial Arbitration and Mediation Services (“JAMS”). The existence, content and result of the arbitration shall be held in confidence by each of us, our representatives, any other participants and the arbitrator. The arbitration will be conducted by a single arbitrator selected by mutual agreement or if we can’t agree, appointed in accordance with the JAMS Rules. The arbitration will be conducted in English and in Austin, Texas. We will each bear our own expenses in the arbitration and share equally the costs of the arbitration, unless the arbitrator assigns costs to one of us. Judgment upon the award rendered in the arbitration may be entered in any court of competent jurisdiction.

Exhibit 1
Energy Retention Warranty
Years 1 through 15 following Start Date:

Per Section 1.2 above, Tesla warrants that during the Warranty Year specified below, as applicable, the Actual Energy Retention Percentage for the Megapack System for such Warranty Year shall be equal to or greater than the applicable Minimum Energy Retention Percentage (below) until the Warranty Year expires or (if earlier) the Total Throughput exceeds the below Total Throughput Limitation for that Warranty Year.

Actual Energy Retention Percentage means the energy discharged by the Megapack System as a whole, as measured at the Point of Measurement defined in the Megapack Sales Agreement (“POM”) at Standard Test Conditions, expressed as a percentage of the Guaranteed Energy Capacity.

Guaranteed Energy Capacity means the kWh energy capacity of the Megapack System set out in the Megapack Sales Agreement.

Total Throughput means the total discharge throughput of the Megapack System (as measured at the POM) in kWh per kWh of Guaranteed Energy Capacity.

Warranty Year means each consecutive 365-day period commencing on the Start Date and each anniversary of that date, as applicable.

Period (Warranty
Years following
Start Date)
Total Throughput
Limitation (2 Hour
Megapacks)
Minimum Energy
Retention
Percentage (2 Hour
Megapacks)
Total Throughput
Limitation (4 Hour
Megapacks)
Minimum Energy
Retention
Percentage (4
Hour Megapacks)
1 339 93.0% 341 93.5%
2 662 88.5% 669 90.0%
3 976 86.0% 990 88.0%
4 1,282 84.0% 1,304 86.0%
5 1,584 82.5% 1,613 84.5%
6 1,879 81.0% 1,914 82.5%
7 2,169 79.5% 2,208 80.5%
8 2,454 78.0% 2,496 79.0%
9 2,733 76.5% 2,779 77.5%
10 3,007 75.0% 3,056 76.0%
11 3,275 73.5% 3,328 74.5%
12 3,538 72.0% 3,595 73.0%
13 3,796 70.5% 3,858 72.0%
14 4,047 69.0% 4,117 71.0%
15 4,294 67.5% 4,372 70.0%
Standard Test Conditions
When measuring the Actual Energy Retention Percentage, (a) the Megapack System must be fully charged to 100% state of energy and then fully and continuously discharged at the Guaranteed Power Capacity (as defined in the Megapack Sales Agreement) to a 0% state of energy, (b) the ambient temperature at the Megapack System location and the initial hourly average ambient temperatures at the Megapack System location recorded during the charge and discharge cycle of the Megapack System of all battery modules must be 25°C ±5°C, and (c) the hourly average ambient temperatures at the Megapack System location recorded during the charge and discharge cycle of the Megapack System must be 25°C ±5°C. Tesla, Inc., 1 Tesla Road, Austin, TX 78725
email: [email protected]

EXHIBIT A
Power Purchase Agreement Between the City of Fairﬁeld and Onyx Development Group LLC., Dated August 26, 2024
Execution Date: 21.1Z'Z
Close Date: A s
Retention Schedu e:`'
Destruction Date: "
r2e

POWER PURCHASE AGREEMENT
by and between
Onyx Development Group LLC
and
City of Fairfield, California

TABLE OF CONTENTS
TABLEOF CONTENTS.............................................................................................................. II RECITALS.................................................................................................................................... 1 AGREEMENT.............................................................................................................................. 2

1. DEFINITIONS........................................................................................................................ 2

2. TERM................................................................................................................................... 2

3. REMOVAL OF SYSTEM.......................................................................................................... 2

4. PURCHASE AND SALE OF OUTPUT AND BATTERY SYSTEMS SERVICES ................................. 3

5. DESIGN, CONSTRUCTION, OPERATION & MAINTENANCE.................................................... 7

6. COMMERCIAL OPERATION DATE; CONDITIONS PRECEDENT; NOTICE TO PROCEED........... 15

7. OWNERSHIP OF SYSTEM, OUTPUT, GREEN ATTRIBUTES AND ENVIRONMENTAL FINANCIAL INCENTIVES........................................................................................................................ 20

8. PAYMENT............................................................................................................................ 20

9. PURCHASE OPTION............................................................................................................ 21

10. EARLY TERMINATION........................................................................................................ 22

11. DELIVERY; RISK OF LOSS; RELOCATION............................................................................ 22

12. METERING......................................................................................................................... 25

13. REPRESENTATIONS, WARRANTIES AND COVENANTS......................................................... 26

14. DEFAULT AND REMEDIES................................................................................................... 27

15. DISPUTE RESOLUTION........................................................................................................ 28

16. TAXES; LIENS.................................................................................................................... 29

17. LIABILITY AND INDEMNITY; INSURANCE........................................................................... 29

18. EASEMENT......................................................................................................................... 31

19. ASSIGNMENT; COOPERATION WITH FINANCING................................................................. 32

20. CONFIDENTIALITY; PUBLICITY........................................................................................... 33

21. LEGAL EFFECT AND STATUS OF AGREEMENT.................................................................... 34

22. MISCELLANEOUS............................................................................................................... 35 11 EXHIBITA - DEFINITIONS............................................................................................................ 40 EXHIBIT B - POWER PRICE AND OUTPUT GUARANTEE RATE .................................................... 46 EXHIBIT C - BATTERY SYSTEMS GUARANTEE RATE...................................................... I........... 49 EXHIBIT D - TERMINATION VALUES........................................................................................... 50 EXHIBIT E - PROJECT DEVELOPMENT SCOPE RESPONSIBILITY................................................ 51 EXHIBIT F - GENERAL CONDITIONS AND TECHNICAL SPECIFICATIONS ................................... 52 iii

POWER PURCHASE AGREEMENT
This Power Purchase Agreement (" Agreement" or " PPA") is made and entered into as of AV% sl— 06, ?"' Zi , (" Effective Date"), between Onyx Development Group LLC (" vider" or " Installer"), and the City of Fairfield, California (" City" or " Site Host").

City andProviderarecollectivelyreferredto hereinas "Parties" andindividually as "Party."

RECITALS
WHEREAS, Provideris in thebusinessof installingandoperatingsolarphotovoltaicand battery energy storagefacilities and selling electric energy generatedfrom such facilities; WHEREAS, Government Code section 4217.10 et seq. provides that public agenciesmay enterinto agreements, including but not limited to, leaseagreements, for real property upon which alternative energy facilities may be constructedsothat the public agencymay purchasethe energy generatedfrom the facilities constructed on the real property under a power purchase agreement; and
WHEREAS, the governing body of City has made those findings required by Section 4217.12of theGovernmentCodethat: (i) theanticipatedcostto City for electricalenergyservices provided by the solar photovoltaic and battery energy storage system under this Agreement will be less than the anticipated marginal cost to City of electrical energy that would have been consumedby City in the absenceof thosepurchasesand (ii) the difference, if any, betweenthe fair market value of the right to accessand occupy the real property subject to this Agreement and related paymentsunder this Agreement, if any, is anticipated to be offset by below -market energy purchasesor other benefits provided under this Agreement; and WHEREAS, City desiresto reduceits energycostsaswell asits dependenceon fossil fuel electric generating resourcesand to promote the generation and storage of electricity from solar photovoltaic and battery energy storagefacilities; and
WHEREAS, Provider desires to design, install, own, maintain, and operate a solar photovoltaic systemincluding all solar photovoltaic panelsand equipment components (the "Solar Facility") and- the battery energy storage system and all equipment components (the " Battery System" or the "Battery Systems") and collectively the " System" or the " Systems" on the real property ( the " Site") owned by the City as describedin Schedule 1 attachedhereto, and Provider shallsellall Outputfrom theSolarFacility andprovideservicesfrom theBatterySystemsto City at thoserates set forth herein (collectively the "Project"); and WHEREAS, Provider hasdeveloped an ownership and financing structure for the System, which facilitates the use of certain tax incentives, and accelerated depreciation to reduce the expected investment returns of its investors, and which benefits City by offering a competitive Power Price, as defined herein; and
WHEREAS, City desires to provide Provider an easement for the sole purpose of accessingCity' s property to install, operate, maintain andrepair the System; and WHEREAS, aspart of this PPA and in consideration of the easement, Provider and City intend that Provider would obtain title, an ownership interest, and retain all financial incentives and tax benefits generated by the System and associatedwith the development of the System, including the installation, ownership and operation of the System and the sale of energy and services from the System to City.

NOW, THEREFORE, in consideration of the promises and the mutual benefits from the covenantshereinafter setforth, thereceipt and sufficiency of which arehereby acknowledged, and intending to be legally bound, Provider and City hereby agreeas follows:

AGREEMENT

1. Definitions.

Capitalized terms used in this Agreement shall have the meanings ascribed to them herein or in the attached Exhibit A.

2. Term.

A. Term. The Term of this Agreement shall commence upon the Effective Date and terminate automatically on the Expiration Date (" Initial Term"), unless terminated earlier as provided herein. City may renew this Agreement for up to two ( 2) five- year renewal terms Renewal Term"). The Initial Term and all subsequent Renewal Terms are referred to collectively as " Term." This Agreement shall terminate automatically and concurrently with any termination of the Site easementprovided by this Agreement.

3. Removal of System.

A. Removal of System. Within one hundred eighty ( 180) Days of the expiration or any termination of this Agreement (unless City has: (i) purchasedthe System under the terms of this Agreement, including, without limitation, all applicable requirementsunder Article 5, below; or ( ii) otherwise consented in writing to allowing the System to remain installed on the Site), Provider shall, in coordination with City and at Provider' s sole cost and expense, remove the System from the Site. Provider shall bear the cost of any required storage of the System, if necessary, during Provider' s removal of the System.

B. Removal and Site Restoration. Removal of the System shall include all installed equipment, including, but not limited to, the System and all tangible and structural support materials, as well as all appurtenant equipment, above and below ground ( except for empty conduits). Provider shall additionally restorethe Siteto a condition substantially similar to the pre - installation condition of the Site, excluding ordinary wear and tear, through reasonable efforts.

Provider' s restoration of the Site shall include, but is not limited to, any refinishing, landscaping, hardscaping, painting or other finish work, and cleaning. Provider shall undertake any repairs necessaryas a result of such removal and restoration. The Parties shall reasonably coordinate all such removal, restoration, storage and transportation activities and dates. 2 C. Failure to Remove. If Provider fails to comply with this Section 3 and remove the Systemandrestore the Site asrequired within suchone -hundred and eighty ( 180) day period, City shall have the right, but not the obligation, to remove the System and restore the Site and charge Provider for the cost incurred by City, which cost shall include a twelve and one-half percent

12. 5%) administrative fee. The Parties shall reasonably coordinate all such removal and pick-up activities. In the event that the Provider doesnot remove the Systemasspecified herein, City shall also have the option of continuing to receive Output from the Solar Facility and Battery Systems Servicesat no cost to City, including, without limitation, no obligation to compensateProvider for the Power Price or other consideration, until the System is removed by either Provider or City.

This Section shall not be interpreted to limit City' s other available lawful remedies.

4. Purchase and Sale of Output and Battery Systems Services.

A. Purchase and Sale of Output. Beginning on the Commercial Operation Date and through the remainder of the Term, Provider agreesto sell and City agreesto buy all Output from the Solar Facility ( the " Solar Facility Output") and Output from the Battery Systems (the Battery Systems Output") at the applicable Power Price assetforth in Exhibit B. City shall have no obligation to pay for Solar Facility Output or Battery Systems Output delivered after the expiration date of this Agreement or the early termination thereof.

B. Cost Reimbursement. The Partiesacknowledgethat City will incur costsassociated with this Project including amounts payable by City to third -party engineers, consultants, legal counsel, and inspectors (" Development Costs"). The Power Price set forth in Exhibit B includes consideration for reimbursement of Development Costs which shall be paid by Provider to City basedon the following schedule:
1) 50% of the Development Costs within 15 days of the Effective Date of this Agreement ( the " Effective Date Milestone");
2) 25% of the Development Costs within 15 days of the date on which City issues Provider a Notice to Proceed to construction; and
3) 25% of the Development Costs within 15 days of the Commercial Operation Date.

C. Adjustment to Power Price; Distribution UtilityUpgrades. The Parties acknowledge that the Power Price set forth in Exhibit B is based on certain assumptions, and that the Power Price may, if ( and only if) the assumptionsprovided in this Section 4(C) are inaccurate, require an adjustment to the Power Price following the Effective Date with thirty ( 30) days' prior written notice to City as follows:
1) Provider assumed that the total cost to be paid to the Distribution Utility in connection with the Distribution Utility Upgrades asstatedin Exhibit B. 2) Provider assumed there shall not be material additional costs to re - design, construct, install or maintain the System due to unforeseen conditions or groundwork at the Site ( including but not limited to excavation/ circumvention of underground obstacles).
3) Provider assumed there are no Hazardous Substances at the Site. 4) The City shall procure, at no material cost to Provider, all planning and zoning permits required for the installation, construction, operation andmaintenanceof the Solar Facility and Battery Systemsby September30, 2024. 5) The City shall by September 30, 2024, either (i) procure, at no material cost to Provider, an exemption for the Solar Facility and Battery Systems from the California Environmental Quality Act (" CEQA") or ( ii) complete CEQA review and obtain approvals for the Solar Facility and Battery Systemsas -designed as of the Effective Date.
6) Provider assumedany information provided by City andrelied upon by Provider is accurate.
7) Provider assumedthat the Project qualifies for the Statistical Area Category of the Energy Communities ITC Adder as outlined in Notice 2024- 30. Power Price under this assumption is listed in Exhibit 2 labeled " 1) 10% ITC Adder Scenario". In the event Provider determines that the Project doesnot qualify for the Statistical Area Category of the Energy Communities ITC Adder as outlined in Notice 2024-30, Power Pricing shall be automatically adjustedto the table within Exhibit 2 labeled 2) Standard 30% ITC. Scenario".

D. Provider' s Solar Facility Output Guarantee. Commencing with the second (2nd) Contract Year after the Commercial Operation Date of the System, and for each Contract Year thereafter during the Initial Term, the aggregatemetered Solar Facility Output for the previous Contract Year ( the " Measurement Period") shall be at leastninety percent (90%) of the Annual Production Estimate for such Measurement Period for the Solar Facility as defined in Exhibit B Output Guarantee"); provided, the Annual Production Estimate is adjusted for actual weather conditions experiencedat the Site, and the Output Guaranteefor any Measurement Period will be reduced by the estimated generation of the Solar Facility that would have been generatedduring such MeasurementPeriod, but was not generated, due to one or more of the following causes: (i) Outage; ( ii) the actions or omissions of the Distribution Utility or the request or direction of the Distribution Utility; ( iii) a Force Majeure event; ( iv) buildings or structures constructed after the Commercial Operation Date overshadowing or otherwise blocking accessor sunlight to the Solar Facility on or at the Site; (v) a breach of this Agreement by City; ( vi) any action or inaction by City that directly causessuch reduction in generation (including but not limited to, pursuant to Sections 5. F, 1LC and I LD below); or (v) a temporary outagepursuant to Section 11.E below.

If the Solar Facility Output during any Measurement Period does not equal or exceed the Output Guarantee for such Measurement Period, Provider shall include in its next invoice to City and in the final invoice for any credit owed for the final Contract Year) a credit for the Energy Shortfall Amount. Alternatively, City hasthe option to requestthat the Energy Shortfall Amount bepaidby checkindependentlyof aninvoice.

E. Provider' s Battery Systems Guarantee. Commencing with the first ( 1st) Contract Year after the Commercial Operation Date of the System, and for each Contract Year until the end of the tenth ( 101h) Contract Year of the Initial Term ( the " Battery Guarantee Term"), the percentageof real time, measuredand reported cumulatively by the supervisory control and data acquisition system, that one hundred percent ( 100%) of the nameplate power capacity of the Battery Systems ( the " Battery Availability") is available for the previous Contract Year ( the 0 MeasurementPeriod) shall be equivalent to at leastninety percent (90%) of the total real time for such Measurement Period ( 8760 hours) (" Battery Systems Guarantee"); provided that, the Parties acknowledge and agreethat the Battery Availability shall be reduced each Contract Year to account for the normal and expected degradation of the Battery System in accordance with manufacturer specifications; and provided further that the Battery Systems Guarantee for any Measurement Period will be reduced by the estimatedreal time that the Battery Systemswould have been available during such MeasurementPeriod, but was not available, due to one or more of the following causes: (i) an Outage; ( ii) the actions or omissions of the Distribution Utility or the requestor direction of the Distribution Utility; ( iii) a Force Majeure event; ( iv) a breach of this Agreement by City, ( v) any action or inaction by City that directly causes such reduction in generation (including but not limited to, pursuant to Sections51, 11.0 and I LD below); or ( vi) a temporary outagepursuant to Section 11.E below. Real time shall be measuredin increments of hours. Provider additionally guarantees that during the Battery Guarantee Term, the Battery Systemswill be available to provide at leastthe number of cyclesper Contract Year (" Guaranteed Cycles") indicated in Exhibit C when using the full Battery Systems kWh Rating. The Battery Systemsshall be cycled in accordancewith standardindustry practices to maximize electricity cost savings to the City. For the absenceof doubt, the Parties acknowledge and agreethat the Battery GuaranteeTermshallterminateattheendof thetenth (1Oth) ContractYear, andthatbeginningon theeleventh (I Ith) ContractYearneithertheBatterySystemsGuaranteenortheGuaranteedCycles shall apply. Provider shall either replace or augment the Battery Systems at the end of the tenth loth) ContractYeartomitigatethedegradationof theBatterySystems. At leastthirty (30) days prior to thetenth (loth) anniversaryof theCommercialOperationDate, thePartiesshallmeetand endeavor in good faith to negotiate a Battery Systems Guaranteefor the remaining fifteen ( 15) Contract Years of the Agreement to preservethe economic value of the Agreement to both Parties.

During the Battery GuaranteeTerm, if the percentageof real time, measuredand reported cumulatively by the supervisory control and data acquisition system, that one hundred percent 100%) of the nameplate power capacity of the Battery Systems is available during any Measurement Period does not equal or exceed the Battery Systems Guarantee for such MeasurementPeriod (eachof the Battery Availability and the Battery SystemsGuaranteeasshall be adjusted in accordance with Section 4. E above), Provider shall include in its next invoice to City a credit for the Battery SystemsEnergy Shortfall Amount. Alternatively, City hasthe option to requestthat the Battery SystemsEnergy Shortfall Amount be paid by check independently of an invoice.

F. Resaleof Output. If at anytime during the term of this Agreement, the City reduces its consumption requirements for Solar Facility Output or Battery SystemsOutput and the Parties determinethat the Distribution Utility is willing to purchaseSolar Facility Output or Battery Systems Output pursuant to any current or future program of the Distribution Utility for net metering, energy credit, offsets or revenue, City, at its option, may sell Solar Facility Output or Battery Systems Output to the Distribution Utility pursuant to such program and in accordance with Section 4(G) below. If applicable and required by law, City may also request that Provider usereasonableefforts to cooperatewith the City andthe Distribution Utility, provided that nothing in the foregoing shall permit the City to sell Solar Facility Output or Battery Systems Output to the Distribution Utility if such sale would limit Provider' s rights and interests in and to this Agreement.
5 G. Net Metering, Credits and Storageof Output. Nothing in this Agreement shall limit City' s ability during the term of this Agreement to participate in or otherwise take advantageof any current or future program which may enable City to store Output or Battery Systems Output at any Site or to export Solar Facility Output or Battery Systems Output to any other site or to the Distribution Utility for any available energy credits, offsets, or revenue. City will give reasonable notice to Provider of its intention to undertake any such project or program and will coordinate with the Provider to ensure that the System, the terms and conditions of this Agreement and all associatedwarranties and guaranteesare preserved, provided that City shall reimburse Provider for any documented and reasonablecosts and expensesassociatedwith such project or program including, if applicable, reimbursement of. lost revenue at City Suspension Rate, loss of any Environmental Financial Incentives, and/or costs associated with any modification, removal, relocation, or temporary or permanent deactivation of the Systemor any portion thereof).

H. Grid ServicesPrograms. From time to time, Provider or City may identify demand responseor similar grid servicesprograms, whereby the Battery Systemscan help meet demands of the electrical grid, or improve its reliability, by charging or discharging the Battery Systems (or agreeingto make theBattery Systemsavailable for charging or discharging) for which the Provider is eligible to participate (collectively, a "Grid Services Program"). Provider shall only enroll the Battery Systemsin any Grid ServicesProgram upon written agreementfrom City. Nothing in this paragraph shall prohibit City from undertaking participation in Grid Services Programs directly when eligible and Provider shall cooperatewith City in ensuring that the Battery Systemsoperates to maximize revenue in relation to any Grid ServicesProgram participation in accordancewith Section I I ( B), provided that City shall reimburse Provider for any documented and reasonable costs and expenses associated with such project or program ( including, if applicable, reimbursement of. lost revenue at City SuspensionRate, loss of any Environmental Financial Incentives, and/or costs associatedwith any modification, removal, relocation, or temporary or permanentdeactivation of the Systemor any portion thereof.

I. Outages. Provider may suspenddelivery of Solar Facility Output or Battery Systems Output as reasonably necessary for testing, maintaining, replacing and repairing the System, or in response to any Distribution Utility directive or dispatch order ( an " Outage").

Provider shall take all stepsnecessaryto minimize the duration and scopeof any such Outage. In the event that an Outageis causedor prolonged by Provider' s negligent act or omission, Provider shall compensate City for the difference between the total electricity cost to the City for the applicable period of outage causedor prolonged by Provider' s negligent act or omission and the Power Price for each 15 minute interval that the Power Price is less than the electricity cost to the City. In such event, City shall provide Provider with evidence of the pricing for such applicable periods in the form of Distribution Utility bills during the outageperiod, andProvider shall provide the calculation and supporting documentation for determining these amounts, to the reasonable satisfaction of City. Except as set forth herein, City waives claims related to City' s costs of purchasing energyto replacewhat would havebeenproducedby the Systembut for suchOutages, along within any associatednet metering, or similar, benefits.

If an Outageoccursunder this Sectionanda paymentis due from Provider to City, Provider shall include in its next invoice(s) to City (and in the final invoice for any credit owed for the final ContractYear) a credit for the difference betweenthe electricity cost to the City for the applicable period.

J. Distribution Utility Electric Service. City may take parallel energy services from Distribution Utility.

5. Design, Construction, Operation & Maintenance.

A. All Provisions in this Article 5 shall apply to all activities of Provider undertaken in relation to the design, construction, installation, maintenance, repair, and operation of the System(s) throughout the Term of this Agreement (eachprovision as applies to the construction or installation of the System, the " Construction Provisions").

B. Provider' s Contractor and Consultants. Provider shall ensure that any party contractingwith Providerfor anyengineering, procurement, design, installationor constructionof the System shall possesssufficient knowledge, experience, expertise, licensing, registration, and financial capacity and creditworthinessnecessaryfor satisfactorycompletion of Provider's obligations under this Agreement. The contractorperforming the construction work on theProject shall possessa Class B or C-10 California Contractor StateLicense, be a registered public works contractor in accordancepursuant to Labor Code Section 1725.5, and all other required licenses for performing work under this Agreement, prior to performing any work on the Project. Provider representsandwarrantsthatit hasthefinancialcapacity, creditworthinessandbondingsufficient to satisfyall of Provider's obligationsunderthis Agreement, including, but not limited to, any instance of default or other failure by Provider' s contractor(s) to complete the work required to satisfyProvider'sobligationsin thisAgreement. Priorto contractingwith anysuchparty, Provider shall obtainandreview the qualificationof suchparty andcompleteanynecessarybackground checkorfingerprintingrequiredby law or City. Providershallfurtherprocurefrom thecontractor performanceandpaymentbondsandanyotherassurancesasProviderdeemsreasonablynecessary to secure contractor' s timely completion of the Project.

C. Permits. Provider shall be solely responsible for ensuring that the System is constructed in compliance with all applicable laws, regulations and Permits, and in accordance with the standardsset by any governmental program providing funding for the System. Provider shall fully includeandincorporateinto any andall designsandengineeringfor the System, all improvements, conditions and mitigation measures required for compliance with the CEQA and where applicable the Americans with Disabilities Act (" ADA"). The City shall, at the City' s sole cost and expense, obtain ( i) all necessary approvals demonstrating that the Systems are in compliancewith CEQAasdesigned, providedthattheCity shallusebesteffortsto obtainwritten confirmation from CEQA, in form and substancereasonably acceptable to Provider, that the Systemis exemptfrom compliancewith CEQA requirements, and (ii) all planning, zoning, and electricalpermitsand/or exemptionsfrom GovernmentalAuthoritieshavingjurisdiction overthe Project required for the installation, operation and maintenance of the System ( clauses ( i) and ( ii) together, the " City Permits" and such City Permits as set forth in Exhibit E attached hereto).

Provider shall, at Provider' s sole cost and expense, obtain from all Governmental Authorities havingjurisdiction overtheProject, all othernecessaryGovernmentalApprovalsandotherPermits andapprovalsrequiredfor the installation, operationandmaintenanceof the System, including, but not limited to fire safety, California Occupational Safety and Health Administration 7 Cal/ OSHA"), utility interconnection, right- of-way permits, easement agreements and other related requirements ( the " Provider Permits" and such Provider Permits as set forth in Exhibit E attached hereto).

Without limiting the City' s obligations with respectto the City Permits, to the extent action is required by City, City shall, upon the request of Provider, use reasonable efforts to assist Provider in obtaining and retaining Provider Permits, licenses, releases and other approvals necessary for the design, construction, engineering, installation, operation and maintenance of the System. Provider shall reimburse City for reasonableand documented costs incurred by City in assisting the Provider under this Section. Provider shall be responsible for all costs, expenses and improvements to the extentrequired to obtain or comply with anypermits, Government Approvals or other requirement under state or federal law made necessary as a result of the System installation, operation and maintenance, except for the City Permits which shall be the sole cost and obligation of the City. Specifically, the Provider is required to obtain and submit all documents to closeout the Project with the Governmental Authorities having jurisdiction over the Project. In addition to stamped and approved plans, Provider shall provide any required installation compliance confirmation letter(s) to any applicable Governmental Authorities.

Provider shall, upon therequestof City, usereasonableefforts to assistthe City in obtaining and retaining the City Permits, provided that the City shall reimburse Provider for reasonableand documented costsincurred by Provider in assistingthe City under this Section.

D. Inspections. Provider and City shall work together reasonably to mutually select any company that performs inspections of the materials and equipmentfor the design, engineering, procurement, construction or installation of the Systems, including, but not limited to, any inspections to verify the Systems' compliance with the Applicable Law.

E. Notice of Output Interruptions. Each Party shall notify the other Party as soon as reasonably practicable following its discovery of any material malfunction of any System or interruption in the supply of electricity from any System. Each Party shall designateand advise the other Party of personnel to be notified in the event of such a malfunction or interruption.

Provider shall correct, or cause to be corrected, the conditions that caused the malfunction or interruption as soon asreasonably practicable. However, in no event shall Provider' s responseto investigate the problem and initiate appropriate corrective action be greater than forty- eight (48) hours following receipt of notice or upon discovery of such malfunction or interruption. In addition, Provider shall remotely monitor the System on a daily basis for the presenceof alarm conditions and generalperformanceutilizing the dataacquisition systemsand monitoring systems installed by the Provider at the Site, as described in Exhibit F.

F. Site Operations. In order to prevent any unreasonabledisturbance or interruption of City activities, ProvidershallaccommodatetheCity'snormaloperationsscheduleandscopeof activities conductedon the Site during construction and on -going operation of the Systempursuant to this Agreement. In the event Provider' s accommodation of the City' s normal operations scheduleresults in a delay to the Project Schedule (as defined below), such Project Schedule and the Commercial Operation Deadline (if applicable) shall be automatically and equitably extended. 8 G. Operation and Maintenance of System. Provider shall be responsible for all operations, maintenance, and repair of the System, except to the extent that any maintenance or repair is made necessaryby the negligent acts or omissions or willful misconduct of City. All maintenance, repairs and operations, shall be conducted in the manner set forth in this Agreement, andProvider shall reasonablyaccommodateand cooperatewith City to ensurethe City' sactivities, facility uses, and scheduling requirements are not unreasonably impeded. Provider' s repair work responsibilities shall include, but are not limited to, any repair required as a result of damage causedby the Provider or its contractors, subcontractorsor vendors, to the City' s facilities within aperiodof five (5) yearsfollowing thedatethedamagewasdiscoveredorreasonablyshouldhave been discovered by the City. Provider is responsible for repairs and/or replacement of system componentsthat aredamagedfrom vandalism, theft or criminal activity. Providershall provide grass cutting services at the Site at least once per calendar year following the Commercial Operation Date for purposes of weed abatementand vegetation control, provided that Provider shall not cut grassor otherwiseprovide vegetationcontrol serviceson any day on which the NationalWeatherServicehasissuedaRedFlagWarningasapplicableto theSite.

H. Prevailing Wages. This Project is subject to compliance with the prevailing wage provisionsof the CaliforniaLaborCodeandtheprevailingwageratedeterminationsof the Department of Industrial Relations. Theseratesareon file at City' smain office or may be obtained online at http//www. dir.ca.g6v/dlsr. A copy of these rates shall be posted at the job site by Provider. Provider and all contractors and subcontractor( s) under it, shall comply with all applicable Labor Code provisions, which include, but are not limited to the payment of not less than the required prevailing rates to all workers employed by them in the execution of this PPA andtheemploymentof apprentices. Providerherebyagreesto indemnifyandholdharmlessCity, their officials, officers, agents, employeesandauthorizedvolunteersfrom andagainstanyandall claims, demands, lossesor liabilities of any kind or naturewhich City, their officials, officers, agents, employeesandauthorizedvolunteersmay sustainor incur for noncompliancewith any applicable Labor Code provisions arising out of or in connection with the Project. 1) Wages.
a. Pursuantto the provisions of Article 2 (commencing at Section 1770), Chapter 1, Part 7, Division 2 of the Labor Code of California, the governing body of City hasascertainedthegeneralprevailingrateof perdiemwagesin thelocality in which this public work is to be performed for each craft, classification, or type of workmen needed to execute the Agreement.
b. Per Diem wages shall be deemedto include employer paymentsfor health and welfare, pension, vacation, travel time and subsistencepay asprovided in Labor Code § 1773.1 apprenticeship or other training programs authorized by Labor Code § 3093, and similar purposeswhen the term " per diem wages" is used herein.
c. Eachworker neededto executethe work mustbe paid travel andsubsistence payments as defined in the applicable collective bargaining agreements in accordance with Labor Code § 1773. 1.
9 d. Holiday and overtime work when permitted by law shall be paid for at a rate of at least one and one-half times the above specified rate of per diem wages, unless otherwise specified.
e. Each worker in work on the System on City' s Property shall be paid not less than the prevailing wage rate, regardlessof any contractual relationship which may be alleged to exist between Provider, or any subcontractors of Provider, and such workers.
f. Provider shall, as a penalty to the City, forfeit an amount as determined by the Labor Commissioner pursuant to Labor Code § 1775 for each calendar day, or portion thereof, for eachworker paid lessthan the prevailing rate asdetermined by the director for suchwork or craft in which suchworker is employed for any public work doneunder the contract by him or by any subcontractor under him.

The difference between suchprevailing wage rate and the amount paid to each worker for each calendar day or portion thereof, for which each worker was paid lessthan theprevailing wagerate, shall bepaid to eachworker by Provider. g. Any worker employed to perform work on the Systemwhich is not covered by any classification available in the City office, shall be paid not less than the minimum rate of wages specified for the classification which most nearly correspondswith work to be performed by him, and that minimum wage rate shall be retroactive to the time of initial employment of the person in the classification.
2) Record of Wages Paid: Inspection. Pursuant to Labor Code § 1776, Provider stipulates to the following:
a. Provider and eachsubcontractorshall keep an accuratepayroll record, showing thename, address, social security number, work classification, straight time and overtime hours worked eachday and week, and the actual per diem wages paid to eachjourneyman, apprentice, worker, or other employee employed by him or her in connection with the Project. Such records shall be on forms provided by the Division of Labor Standards Enforcement or shall contain the same information of suchforms. The payroll recordsmay consist of payroll datathat are maintained as computer records, if printouts contain the same information asthe forms provided by the division and the printouts areverified asspecified in subdivision ( a) of Labor Code § 1776.
b. The payroll recordsenumeratedunder subdivision (a) shall be certified and shall be available for inspection at all reasonablehours at the principal office of Provider, or Provider' s subcontractors, on the following basis:
c. A certified copy of an employee's payroll record shall be made available for inspection or furnished to such employee or his or her authorized representative. 10 d. A certified copy of all payroll records enumeratedin subdivision ( a) shall be made available for inspection or furnished to a representative of the City, and to the Division of Labor Standards Enforcement, and Division of Apprenticeship Standards of the Department of Industrial Relations.

A certified copy of all payroll records enumerated in subdivision ( a) shall be made available to the public for inspection or copies thereof, subject in all respectsto subclause (g) below. However, arequestby thepublicshallbemade through either the City, the Division of Apprenticeship Standards, or the Division of Labor StandardsEnforcement. If the requestedpayroll recordshave not been provided pursuant to the above, the requesting party shall, prior to being provided the records, reimburse the costs of preparation by Provider, subcontractors, and the entity through which the requestwas made. The public shall not be given accessto such records at the principal office of Provider or Provider' s subcontractors.
f. Provider shall file, or caused to be filed, a certified copy of the records enumeratedin subdivision (a) with the entity that requestedsuchrecordswithin ten ( 10) days after receipt of the written request.
g. Any copy of recordsmadeavailable for inspection ascopiesand furnished upon request to the public or any public agency, by the City, the Division of Apprenticeship Standards, or the Division of Labor Standards Enforcement shallbemarkedor obliteratedin sucha mannerasto preventdisclosureof an individual' s name, addressand social security number. The name and address of Provider or subcontractors performing the work shall not be marked or obliterated. Any copy of recordsmade available for inspection by, or furnished to, a joint labor-managementcommitteeestablishedpursuantto the federal Labor Management Cooperation Act of 1978 ( Section 175a of Title 29 of the United StatesCode) shall be marked or obliterated only to prevent disclosure of anindividual' snameandsocial security number. Notwithstanding any other provision of law, agencies that are included in the Joint Enforcement Strike Force on the Underground Economy establishedpursuant to Section 329 of the Unemployment Insurance Code and other law enforcement agencies investigating violations of law shall, upon request, be provided non -redacted copies of certified payroll records.
h. Provider shall inform the City of the location of the records enumeratedunder subdivision ( a), including the streetaddress, city, and county, and shall, within five ( 5) working days, provide a notice of a changeof location and address.

In the event of noncompliance with the requirements of this Section, Provider shall have ten ( 10) days in which to comply subsequentto receipt of written notice specifying in what respects Provider must comply with this Section.

Shouldnoncompliancestill beevidentaftersuch10-dayperiod, Providershall 11 pay a penalty in the amount prescribed by statute to the City for eachcalendar day, or portion thereof, for eachworker, until strict compliance is effectuated.

Upon the request of the Division of Apprenticeship Standardsor the Division of Labor StandardsEnforcement, such penalties shall be withheld from the progresspayment then due.
j. The responsibility for compliance with this Section shall rest upon Provider. 3) Hours of Work.
a. As provided in Article 3 ( commencing at Section 1810), Chapter 1, Part 7, Division 2 of the Labor Code, Provider stipulates that eight ( 8) hours of labor shall constitute a legal day' swork. The time of service of anyworker employed at any time by Provider or by the work or upon any part of the work contemplatedby this contract is limited and restricted to eight (8) hours during any one calendarday and forty (40) hoursduring any onecalendarweek, except ashereinafterprovided. Notwithstanding theprovisions herein, work performed on the City' s Property by employees of Provider or employees of any subcontractors of Provider in excess of eight ( 8) hours per day and forty ( 40) hours during any one week upon this public work shall be permitted provided that compensation for such employee of all hours worked in excess of eight ( 8) hours per day is not lessthan one and one-half times the basic rate of pay. b. Provider shall pay to the City a penalty in the amount prescribed by statute for each worker employed in the execution of these Construction Provisions by Provider or by any Subcontractor for each calendar day during which such workman is required or permitted to work more than eight ( 8) hours in any calendar day and forty ( 40) hours in any one calendar week in violation of the provisions of Article 3 ( commencing at Section 1810), Chapter 1, Part 7, Division 2 of the Labor Code, unless compensation to the worker so employed by Provider is not lessthan oneand one-half ( 1-1/2) times the basic rate of pay for all hours worked in excess of eight ( 8) hours per day. c. Any work necessaryto be performed afterregular working hours, or on Sundays or other holidays shall be performed without additional expense to City, unless otherwise agreed to by the parties.
d. Construction work under the Construction Provisions shall be accomplished on a schedule consistent with the normal and reasonable practices of Provider and in compliance with applicable ordinances.
4) Apprentices.
a. All apprentices employed by Provider to perform services under these Construction Provisions shall be paid the standard wage paid to apprentices under the regulation of the craft or trade at which that apprentice is employed, 12 and shall be employed only at the work of the craft or trade in which that apprentice is registered. Only apprentices, as defined in Labor Code § 3077, who are in training under apprenticeship standardsand written apprenticeship agreements under Chapter 4 ( commencing at Section 3070), Division 3 of the Labor Code, are eligible to be employed under these Construction Provisions.

The employment and training of each apprentice shall be in accordancewith the provisions of the apprenticeship standardsand apprenticeship agreements under which that apprentice is training.
b. When Provider to whom the work under these Construction Provisions is awardedby the City or any Subcontractorunder Provider, in performing any of the work under the Construction Provisions, employs workers in any apprenticeablecraft or trade, Provider andSubcontractor shall apply to thejoint apprenticeship committee administering the apprenticeship standards of the craft or trade in the area of the Site of the public work, for a certificate approving Provider or Subcontractor under the apprenticeship standards for the employment and training of apprentices in the area or industry affected.

However, approval as established by the joint apprenticeship committee or committees shall be subject to the approval of the Administrator of Apprenticeship. Provider or subcontractors shall not ' be required to submit individual applications for approval to local joint apprenticeship committees provided they are already covered by the local apprenticeship standards. The ratio of work performed by apprenticesto journeymen, who shall be employed in the craft or trade on the public work, may be the ratio stipulated in the apprenticeship standards under which the joint apprenticeship committee operates, but in no case shall the ratio be less than one hour of apprentice work for eachfive ( 5) hours of labor performed by ajourneyman, except asotherwise provided in Section 1777.5 of the Labor Code. However, the minimum ratio for the land surveyor classification shall not be less than one apprentice for each five journeymen.
c. " Apprenticeable craft or trade" as used in Labor Code § 1777. 5 and this Article, means a craft or trade determined as an apprenticeable occupation in accordance with rules and regulations prescribedby the Apprenticeship Council. d. Provider, or any Subcontractorwhich, in performing any of the work under this contract, employs journeymen or apprentices in any apprenticeable craft or trade andwhich is not contributing to a fund or funds to administer and conduct the apprenticeship programming of any craft or trade in the area of the Site of the public work, to which fund or funds other Providers in the area of the Site of the public work are contributing, shall contribute to the fund or funds in each craft or trade in which that Provider employsjourneymen or apprenticeson the public work in the same amount or upon the same basis and in the same manner as other Providers do, but where the trust fund administrators are unable to acceptthe funds, Providers not signatory to the trust agreement shall pay like amount to the California Apprenticeship Council. Provider or Subcontractor 13 may add the amount of such contributions in computing their bid for the contract. The Division of Labor Standards Enforcement is authorized to enforce the payment of the contributions to the fund or funds as set forth in Labor Code § 227.The responsibility of compliance with Labor Code § 1777. 5 and this Article for all apprenticeable occupations is with Provider. e. The interpretation and enforcement of Sections 1777. 5 and 1777. 7 of the Labor Code shall be in accordancewith the rules and procedures of the California Apprenticeship Council.

I. Safety Precautions and Programs. Provider shall ensure that its contractor and subcontractorsperforming work on the Site comply with the following safety precautions. 1) Provider'scontractor shall beresponsiblefor initiating, maintaining andsupervising all safety, precautionsand programsin connectionwith the constructionand installation of the Systems, for maintaining all safety andhealth conditions on each site andfor ensuring againstand/or correcting any hazardousconditions on the site. 2) Certainwork may be ongoingduring City' s working hours; therefore, Provider's contractor shall takeprecautionsto prevent injury andin accordancewith the City' s guidelines for onsite safety. Material storageand vehicle accessand parking shall be subjectto City approval. In the eventCity' s failure to approveor failure to timely approve results in a delay to the Project Schedule (as defined below) or otherwise delays Provider' s satisfaction of any obligations hereunder, the Project Schedule, the Commercial Operation Deadline ( if applicable), and any other applicable schedule of Provider shall be automatically and equitably extended and the City shall reimburse Provider for any reasonable or documented costs and expenses incurred in finding alternative locations.
3) The use of alcohol, drugs, or tobacco will not be permitted on City property.

Workersemployedby Provider's contractoror subcontractors. All workerswill present themselves with appropriate language,. actions and work wear while on construction site and follow requirements from City for interaction with City' s stakeholders.
4) Provider' s contractor shall designate a responsible member of its organization at the Site whose duty shall be the prevention of accidents and overall jobsite safety for contractor/ subcontractor employees and visitors.

J. Conduct of Project Construction, . Installation, Alteration, Operation, Repair, Maintenance and Removal. Throughout the Term of this Agreement, all work of construction, installation, alteration, operation, repair, maintenance and removal of the Projects shall conform with the following:
1) Provider shall not leave debris under, in, or about the Site, but shall promptly remove same from the Site and dispose of it in a lawful manner. 14 2) Provider shall promptly remove all rubbish and debris left by Provider or Subcontractorduring the period of its active activities at the Site. 3) When performing activities at a Site, Provider shall enclosethe working areawith temporary fencing. If the Site is operatedby a school, the fencing shall be adequate to keep studentsout of the work area and physically segregatedfrom any and all workers on or about the Site. Provider shall coordinate with City' s designated contact to develop a mutually agreeableschedule for any activity at the Site to mitigate any inconvenience to or disruption of students, faculty, and staff in their regular activities and to otherwise eliminate any substantial interference with normal operations of the Site.
4) Provide fencing and/or demarcations around any shrubs or trees indicated to be preserved, provided that such indication is provided in writing by City to Provider prior to initiation of any installation or construction work by Provider, sufficient to protect such foliage from substantial damage that might ordinarily occur during activities of the kind undertaken by Provider at the Site. 5) Deliver personnel, tools, equipment and materials to the work area over route(s) reasonably designatedby the City, provided that City ensuresthat Provider shall haveall accessrightsnecessaryto usesuchdesignatedroutes. 6) Take commercially reasonable measures to mitigate objectionable dust, noise, or other disturbances as necessaryto ensure Provider' s activities do not result in substantial interference with or disruption of regular Site activities and normal operations of the Site.
7) Confine apparatus, the storage of materials, and the operations of workers to limits indicated by law, ordinances, permits or the reasonabledirections of the City, not unreasonably encumber Site or overload any structure with materials, enforce all reasonableinstructions of the City regarding signs, advertising, fires, and smoking and require that all workers comply with all City' s regulations while on the Site. 8) Upon completion of activities on the Site, Provider shall remove temporary utilities, fencing, barricades, planking, sanitaryfacilities andall similartemporaryfacilities from Site.
9) Providershallremainstrictlyliableto City for all damagesto City'spropertycaused or contributed to by Provider, its employeesand/or agentsand shall, upon written demandby City, restoreall City propertydamagedby Provider, its employees and/or agentsto substantiallythe conditionin which it wasprior to saiddamage occurring at the sole cost and expenseof Provider, excepting ordinary wear and tear.

6. Commercial Operation Date; Conditions Precedent; Notice ; to Proceed. 15 A. City Conditions Precedent to Construction. City' s obligations under this Agreement -are conditioned on the completion of the following pre -construction activities relating to the System (" City Conditions Precedent"), or the City' s written waiver of such conditions, within one hundred and eighty ( 180) days after the Effective Date (" Conditions Precedent Deadline"):
1) Provider shall have completed all design and engineering of the Systems) in accordancewith the requirementsof Article 5, above, including, without limitation, having obtained all necessary approvals, Provider Permits and entitlements precedent to construction or installation.
2) Provider shall submit to City certificates of insurance and endorsements demonstrating compliance with the requirements defined in Section 17 of this Agreement and carriage of workers' compensation insurance. 3) Provider shall submit to City the certificates in a form provided by City regarding compliance with statutory studentsafety (if applicable), tobacco use and drug use. 4) Provider shall submit to City a fully executedcopy of any and all contracts entered into for the engineering, procurement and/or construction of the System, provided Provider may redact confidential and commercial information. 5) Provider shall submit to City for approval a 90% completed design of the System, a detailed construction andinstallation schedule (such scheduleasmay be updated or amended, the " Project Schedule") and a detailed project safety plan. Provider' s construction and installation schedule shall include start and completion dates for all categories of work on the Site, including but not limited to pre -construction activities, installation of major equipment and anticipated Site deliveries and all required submittal and procurement documentation.
6) Provider shall confirm to City that Provider has obtained and secured sufficient financing to fund Provider' s obligations under this Agreement.

B. Provider Conditions Precedent to Construction. Subject to Provider' s commercially reasonable efforts, Provider' s obligations under this Agreement are conditioned on the completion of the following conditions (" Provider Conditions Precedent") to Provider' s reasonable satisfaction, or Provider' s written waiver of such conditions, on or before the Conditions Precedent Deadline:
7) The City shall submit evidence to Provider, in form and substance reasonably acceptableto Provider, that the City has obtained or causedto be obtained all City Permits.
8) Provider hasdetermined, in accordancewith standardindustry practices, that there do not exist site conditions ( including environmental conditions) or construction requirements that were not known as of the Effective Date and that could 16 reasonablybe expectedto materially increasethe cost of installation, operation and maintenance of the Solar Facility or Battery System or would adversely affect the sale and delivery of Solar Facility Output and Battery SystemsOutput to the City as designed.
9) Provider has determined, in accordancewith standard industry practices, that the Site, as is, is sufficient to accommodate the System and suitable for construction and operation of the Solar Facility andBattery System.
10) The City shall transfer the Distribution Utility' s approved interconnection application to the Provider and Provider has determined, in accordance with standard industry practices, that interconnection services will be available with respect to energy generated by the Solar Facility. Provider shall take over the responsibility of managing the interconnection application originally submitted by the City to the Distribution Utility and undertake all commercially reasonable efforts to assessthe capacity of the Distribution Utility facilities, including, but not limited to, the applicable transformer(s) and conductor(s) and provide a written assessmentof such to City.
11) Provider hasdetermined, in accordancewith standardindustry practices, that there hasnot occurred amaterial adversechangein the regulatory environment, incentive program or federal or statetax codethat could reasonablybe expectedto adversely affect the economics of the installation for Provider.
12) Providerandthe City shallhaveexecutedsuchdocumentsasreasonablyrequired to protect Provider' s rights in and use of the Site in accordance with Section 18 hereof.

C. Completion of Condition Precedent to Construction; Termination. If Provider is unableto timely completeany of the City ConditionsPrecedentby the ConditionsPrecedent Deadline, City may, but is not required to, either (i) waive or extend suchrequirements in awritten notice to Provider; or ( ii) terminate this Agreement without triggering .the default provisions of this Agreement, including, but not limited to any default provision requiring the payment of the Termination Value, nor shall any such termination subject City to any other liability. If Provider is unable to complete or confirm, as applicable, any of the Provider Conditions Precedentby the Conditions Precedent Deadline, Provider may, but is not required to, either ( i) waive such requirement in a written notice to City; or (ii) terminate this Agreement without triggering the default provisions of this Agreement and receive a reimbursement of fifty percent (50%) of the Development Cost paid by Provider to City as of such termination date. Upon the satisfaction of all City Conditions Precedentand Provider Conditions Precedent, and written confirmation from Provider of the same, City shall issuea notice to proceedto Provider (" Notice to Proceed") within ten ( 10) businessdays, informing Provider that it may commencethe construction of the System on the Site. Provider shall not proceed with construction of the Systemuntil it has received the Notice to Proceed. Upon City' s reasonablerequest, Provider shall promptly provide City with copies of any requestedforms, documentsand communications received or generatedby Provider in connection with this Agreement.
17 D. Construction; Commercial Operation. Promptly upon receipt of the Notice to Proceedto construction from City, Provider shall commenceconstruction of the System, and shall causethe submission of final electrical clearanceto the Distribution Utility prior to the net energy metering (NEM) deadline which is set for April 15, 2026 (the " NEM Submission Deadline").

Provider shall cause complete installation and start-up of Commercial Operation thereof on or before the date as indicated in Attachment C in Exhibit F ( the " Commercial Operation Deadline"). The Commercial Operation Deadline shall be on or prior to June 15, 2026. Prior to declaringCommercialOperation, Providershallachievethefollowing:
1) Effect the execution, in coordination with City, of all agreements required for interconnection of the System with the Distribution Utility, including, without limitation, the Interconnection Agreement and net metering agreement if applicable; and
2) Ensure that all necessaryconnections and equipment are installed in compliance with all applicable codes and standards, and that Provider hasprocured or caused the complete installation of all necessary equipment and protection devices to enable delivery of Solar Facility Output and the Battery SystemsOutput from the Delivery Point to City' s facilities.
3) Obtain or cause to be obtained all necessaryPermits, entitlements, contracts and agreements required for the operation and maintenance of the System and the sale and delivery of Solar Facility Output and the Battery SystemsOutput to City. 4) Provide written confirmation that ( i) all required commissioning has been completed; (ii) City and its agentshavebeenprovided accessto the monitoring data for the System at the level required by this Agreement; and ( iii) all closeout activities outlined in Section 7 of Exhibit F have been completed.

E. Commercial Operation: The " Commercial Operation Date" shall be the date on whichProvideraccuratelynotifiesCity of thefactthattheSystemismechanicallyandelectrically completeandoperationalandprovidingSolarFacility OutputandBatterySystemsOutputthrough the Meter( s) to the Delivery Point under approved and executed Distribution Utility Interconnection Agreement and that Provider has met all of the requirements in Section 6( D) above. Provider shall cause the Commercial Operation Date to occur on or before the Commercial Operation Deadline.

The City shall be solely liable for any delays causedby the City or the City' s contractor(s).

Any delaycausedby theCity or theCity' s contractor(s) shallresultin a day -for -daypushof the ProjectSchedule. TheCity shallbe solelyliable for anydemobilizationandremobilizationcosts incurred due to any delay causedby the City or the City' s contractor(s). For the absence of doubt, if the City hasnot completedthe High Lift upgradeproject (PM#35228024) on or beforeMarch 29, 2026, both the NEM Submission Deadline and the Commercial Operation Deadline shall be automaticallyextendedto provide for the delaysto Provider and Provider's contractor(s) in completingthe work. Providershall deliver to City a revisedProject Schedule, and any Delay Liquidated Damagesshall be assessedsolely basedon suchrevised Project Schedule.

Provider shall be solely liable to City for any delay by Provider or Provider' s contractor(s) in completing the work, including any costsof City associatedwith impacts to the Site or a delay in the Commercial Operation Date.

If Commercial Operation has not commenced on or before the thirtieth ( 30th) day following theCommercialOperationDeadline (asmaybeextendedasprovidedherein), City may, but shall not be required to, assessDelay Liquidated DamagesagainstProvider in anamount equal to $300 per Day. If Commercial Operation has not commenced on or before the ninetieth ( 90th) day following the Commercial Operation Deadline, City may, but shall not be required to, terminate this Agreement without triggering the default provisions of this Agreement asto City or any other City liability, including any default provision which would otherwise require payment of the Termination Value, provided that the City shall not terminate this Agreement if the City determines, in its reasonable discretion, that Provider continues to diligently pursue, using commercially reasonable efforts, the achievement of Commercial Operation. If submission of final electrical clearanceto the Distribution Utility hasnot occurred on or before the NEM Submission Deadline, City may, but shall not be required to, assessDelay Liquidated Damages against Provider in an amount equal to $300 per Day.

The cost to City for administration, inspection, mileage, and other similar items would be extremely difficult to determine. For that reason, additional liquidated damages, known as Administrative Delay Liquidated Damages may also be applied to compensate City for undue delays in the completion of punch list items, Final Binder ( as defined in the General Conditions and Technical Specifications attached hereto as Exhibit F), site clean-up, anddemobilization, after Commercial Operation has been achieved. Provider shall complete site clean-up and demobilizationwithin thirty ( 30) days of CommercialOperationDate. At any time after the expiration of such 30-day period, the City shall provide written notice to Provider of any outstanding work the City reasonably determines Provider must complete. If Provider has not curedsuchissueswithin fifteen (15) daysof receiptof suchnotice (asshall be extendedby an additional fifteen ( 15) days if Provider is diligently pursuing such cure), Administrative Delay Liquidated Damages shall be imposed in the amount of $250 per day. Charges will be assessed until City reasonably agreesthat all outstanding work hasbeencompleted.

F. Extension of Commercial Operation Deadline. Provider may request in writing an extensionof theCommercialOperationDeadline. At thetimeof therequest, Providershallpresent City in writing with the reasonfor delay, confirmation that Commercial Operation shall commence within therequestedextensiontime aswell asevidencedemonstratingthatthedelayin achieving the Commercial OperationDeadline could not have been reasonablyavoidedby Provider.

Provider's written requestmust also state the date on which Provider reasonablybelieves CommercialOperationwill beachievedfollowing suchextension. Theapprovalof therequestwill beatthesolediscretionof City andif approvedby City, Providershallpayto City anon-refundable extension fee of $ 350 for each request, provided that no extension fee shall be payable and the Commercial Operation Deadline shall automatically be extendedby one day for eachday of delay caused by: ( i) a Force Majeure event, ( ii) any action of the City that directly causedsuch delay includingbut not limited to pursuantto Sections5.17and5_I above), or (iii) any delay by City in 19 obtainingtheCity PermitsbeforeSeptember30, 2024. To theextentthatProviderfails to meetthe Commercial Operation Deadline as automatically extended or extended by City pursuant to this Section, City shall have the options to terminate or assessliquidated damages as set forth in subsection E above.

7. Ownership of System, Output, Green Attributes and Environmental Financial Incentives.

A. Ownership of System. Title to the System shall remain with Provider during the Term unless and until City exercisesits option to purchasethe System as set forth herein. None of the System, including, but not limited to any componentsthereof may be sold, leased, assigned, mortgaged, pledged or otherwise alienated or encumberedby City. City shall not causeor permit the System or any part thereof to become subject to any lien, encumbrance, pledge, levy or attachmentarising by, under or through City. If there is any mortgage or fixture filing against the Site which could reasonablybe construed as attaching to the System as a fixture of the Site, City shall provide or procure, at Provider's request,. a disclaimer, releaseor subordinationandnon - disturbanceagreementfrom suchlien holder. City shall not unreasonablywithhold consentsto the filing by Provider, on behalf of City, of a disclaimer of the System as a fixture of the Site in the office where real estaterecords are customarily filed in thejurisdiction of the Site. Provider shall bear all risk of loss with respect to the System, except for losses arising from the negligence or willful actsor omissionsby City, or their agentsor -employees. Provider shall besolely responsible for the System operation and maintenance in compliance with all applicable laws, regulations and Permits. Provider shall not be responsible for the cost or expenseof any maintenancerequired as a direct result of City' s negligence or willful misconduct.

B. Ownershipof Output, GreenAttributes and EnvironmentalFinancialIncentives.

Provideris the exclusiveowner of any EnvironmentalFinancialIncentivesassociatedwith the construction, ownership and operation of the System. City will assign its interest (if any) in all such credits and other financial incentives to Provider. City is the exclusive owner of, and may assign or sell in its sole discretion, all Green Attributes, including, but not limited to, Renewable Energy Certificates (" REC"), and REC Reporting Rights, attributable to the System and the Solar Facility Output or Battery SystemsOutput therefrom. Without additional chargeto City, Provider shall take and bearthe costsof all stepsnecessaryto secureandperfect City' s interest in the Green Attributes, including, but not limited to, registering the RECs with WREGIS. The Parties agreeto subsequentlynegotiate in good faith the ownership of any additional benefit or incentive associated with this Agreement which did not exist at the time this Agreement was entered into.

8. Payment.

A. Monthly Invoices. Provider shall provide an invoice for the System to City on a monthlybasis, by the 15thdayof eachcalendarmonthfollowing theCommercialOperationDate of the System. Each invoice will set forth ( i) the Solar Facility Output and/or Battery Systems Output delivered in the preceding month, (ii) the Power Price for suchmonth, (iii) the total amount to bepaid by City to Providerfor SolarFacility Outputand/or BatterySystemsOutputdelivered in the preceding month, (iv) the year and month of the PPA term, (v) Annual Production Estimate for the relevant year assetforth in Exhibit B, (vi) running total of Annual Production Estimate for the relevant year as set forth in Exhibit B versus cumulated actual Output for the relevant year, 20 vii) running total of Battery Systems Guaranteefor the relevant year as set forth in Exhibit C versus cumulated actual Battery Systems Output for the relevant year (viii) and any applicable offsets or credits to such invoice amounts.

B. Due Date. All payment of invoices shall be in U.S. Dollars and paid by wire transfer, check, or automated- check handling (ACH) payment delivered to Provider at the address specified herein within forty- five ( 45) Days of the date the invoice is received by City (" Due Date"). If the Due Date is a weekend or a bank holiday, payment will be due the next following businessday.

C. Payment Disputes. In the event a Party disputes all or a portion of an invoice, or any other claim or adjustment arises, such disputesshall be resolved pursuant to Section 15.

9. Purchase Option.

A. Purchase of System. Unless City is in default of its obligations under this Agreement, City shall have the option to purchaseall of Provider' s right, title, and interest in and to theSystemon (i) theseventh (7th) anniversaryof theCommercialOperationDateandoneach anniversary of the Commercial Operation Date thereafter, (ii) upon expiration of the Term hereof, or (iii) asotherwise provided herein (" Purchase Option"). If City wishes to exercise its Purchase Option, it must provide notice to Provider at least ninety ( 90) Days in advance of any such anniversary or the expiration of the Term. The purchaseprice shall be the greater of ( i) the Fair Market Value, as defined under this Agreement, of the System as of the applicable anniversary dateor theexpirationof theTermor (ii) theTerminationValuefor theyearin which thePurchase Option is exercised ( the " Purchase Price"). Upon the exercise of the Purchase Option and Provider' sreceipt of all amountsthen owing by City under this Agreement, including any incentive or depreciationrecapture, the Partieswill executeall documentsnecessaryfor the purchaseand sale of the System, including but not limited to, the delivery of the PurchasePrice, the transfer of title to the System, and to the extent transferable, the remaining period, if any, on all warranties and Green Attributes for the System to City. Provider shall remove any encumbrancesplaced or allowed on the Systemby Provider. On the dateon which Provider transferstitle to the Systemto City in accordancewith this Section, this Agreement shall terminate without default or penalty to City.

B. Fair Market Value.. The " Fair Market Value" of the System shall be the value thereof as determined by a nationally recognized independent appraiser selected by the Parties, with experienceand expertisein the solar photovoltaic andbattery energystorageindustry to value such equipment. The Fair Market Value of the System shall be based upon its fair market value in continued use for the Term, taking into account, among other things, the age, condition and performance of the System and advancesin solar technology, provided that installed equipment shallbe valuedon aninstalledbasis, shallnot bevaluedasscrapif it is functioning andin good condition and costs of removal from a current location shall not be a deduction from the valuation, taking into accountthe presentvalue of all associatedfuture income streamsexpectedto arise from the operation of the System for the remaining useful life of the System, including but not limited to the expected price of electricity. The appraiser will consider the loss of all Environmental Financial Incentives or any other tax benefits related to the System, and including the costs of removal, shipping andreinstallation, asa costcredit againstthe value of the System. The valuation 21 made by the appraiser shall be binding on the Parties in the absenceof fraud or manifest error.

The costs of the appraisal shall be borne by the Parties equally. If the Parties are unable to agree on the selection of an appraiser, such appraiser shall be selected by the two appraiser firms proposedby eachParty.

10. Early Termination.

A. Provider' s Early Termination Rights. Provider shall have the right, but not the obligation, to terminate this Agreement without triggering the default provisions of this Agreement or any liability under this Agreement prior to expiration of its. Term upon the occurrenceof:
1) An unstayed order of a court or administrative agency, or a change in state or federal law or regulation ( a " Change in Law"), imposing a material cost, regulation or other requirement upon the sale of Solar Facility Output or Battery Systems Output which precludes the Provider from providing Solar Facility Output or Battery SystemsOutput pursuant to this Agreement. Provider shall notify City of any such Changein Law, and within thirty ( 30) daysfollowing receipt by City of suchnotice, the Parties shall meet and attempt in good faith to negotiate such amendmentsto this Agreement as are reasonably necessary to preserve the economic value of this Agreement to both Parties. If the Parties are unable to agree upon such amendments within such30-day period, then either Party may terminate this Agreement. 2) Condemnation, destruction, or other material damage to the Site that results in the termination of the easement to such Site.

In the event Provider exercises its right under this Section, City may elect to either ( i) purchase the System pursuant to Section 9 as of the time of Provider' s notice; or ( ii) require Provider to remove the System within one hundred eighty ( 180) days at Provider' s sole cost and expense and restore the Site as required in Section 3.

B. Ci . ' s Early Termination Rights. If City ceasesto conduct operations at or vacates a Site, City may, upon payment to Provider of the Termination Value and of all amounts then owingby City underthisAgreement, netof amountsor receivablesthenowedto City by Provider, without further penalty hereunder, terminate this Agreement. Provider shall remove the System at the Site in accordance with Section 3.

11. Delivery; Risk of Loss; Relocation.

A. Output Specifications. Provider shall ensure that all energy generated and / or dischargedby the System conforms to Distribution Utility specificationsfor energy being generatedand / or dischargedanddeliveredto theelectricdistributionsystemsof the Site, which shall includethe installationof properpower conditioningand safetyequipment, submittal of necessaryspecifications, coordinationof Distribution Utility testing and verification, and all related costs.
22 B. Transfer of Output. Provider shall be responsible for the delivery of Solar Facility Output and Battery Systems Output to the Delivery Point. Provider shall undertake all commercially reasonableefforts to assessthe capacity of the Distribution Utility transformer(s) and conductor( s). To the extent any subsequent upgrade to such facilities is required and not performed and funded by the Distribution Utility, the Provider shall causesuch upgrades to be completed at its sole cost and expense, subject to adjustment of the Power Price as contemplated by Exhibit B. Title and risk of loss of the Solar Facility Output and Battery SystemsOutput shall passfrom Provider to City upon delivery of the Solar Facility Output andBattery SystemsOutput to the Delivery Point. To the extent applicable to the Project, prior to the start of construction of the System, Provider shall use commercially reasonableefforts to assistwith City' s selection of equipment installations on City' s side of any Delivery Point.

C. Relocation. On or after the seventh (7th) anniversary of the Commercial Operation Date, City may, at its option, require that the System be permanently relocated, either on the existing Site or to another site of City' s choosing, at a location with at leastequal insolation to the existing Site and reasonably acceptableto both Parties (the "Relocation Site"). City shall give Provider at least sixty ( 60) calendar Days' notice of City' s need to move or relocate the System.

Following agreement on a Relocation Site, the Parties will amend this Agreement to memorialize the required changes in the definition of " Site."
City shall pay the reasonablecostsarising in connection with the relocation of the System, including removal costs, necessarystoragecosts, re -installation, re -commissioning costs, and any applicable interconnection fees, provided that Provider provides City with information detailed herein below in a timely manner. City shall additionally compensate. Provider for any revenue duringtheperiodin which energycannotbegeneratedanddeliveredto City from theSystembeing relocated, at City SuspensionRate, asdefined below, prorated asneededto apply on a daily basis.

City shall also execute such consents or releasesreasonably required by Provider or Provider' s financing Parties in connection with the relocation. Within thirty ( 30) Days of agreementon a Relocation Site, Provider will provide City with a calculation of the estimated time required for such relocation, and the total anticipated amount of lost revenues and additional costs to be incurred by Provider asa result of suchrelocation. City will have twenty (20) Days to review the calculation and make, in writing, any objections to the calculation. Provider shall make all commercially reasonable efforts to achieve the relocation of the System in the estimated time and for the estimated cost provided to City. All additional time and / or costs shall require advance written approval of City.

If an acceptable Relocation Site cannot be located, this Agreement shall terminate with respectto the Site, upon Provider' sthirty ( 30) Days' written notice. In the eventthat anacceptable Relocation Site cannotbe agreedupon, City shall pay Provider an amount equalto the Termination Value. In the event of a termination occurring under this Section, Provider shall remove the SystemandrestoretheSitein accordancewith Section3, atno additionalcostto City.

D. TemporarSuspension by City. Notwithstanding any other provision of this Agreement, City shall have the right, upon written notice to Provider, to temporarily suspend operationsandSolarFacility Outputand/orBatterySystemsOutputfor anyreason. City shallhave the right, upon written notice to Provider, to temporarily render the Systemnon -operational for up 23 to forty- eight (48) hoursper year without penalty or chargeby Provider. If City requires temporary suspensionof the System for more than forty- eight (48) hours in a given year, City shall pay to Provider an amount, prorated asnecessary, equalto the amount of the monthly payment for power purchasedpursuant to this Agreement for the samemonth(s) (or portion thereof) in the preceding twelve ( 12) months, or for the average of the entire period the System has been in Commercial Operation if lessthan twelve ( 12) months, for theperiod of time during which the Systemis not in Commercial Operation in excessof forty- eight (48) hours (" City Suspension Rate") due to the temporary suspensionby City.

E. Temporary Suspensionby Provider. Provider shall have the right, upon written notice to. City, to temporarily render the System non -operational for up to forty- eight (48) hours peryearwithout penaltyor chargeby City. If Providerrendersthe Systemnon -operationalfor a periodin excessof forty-eight (48) hours, Providershallpayto City amonthlypayment (prorated as needed) equal to the difference between 'the cost to the City of purchasing energy for the combined servicesof theDistribution Utility and City during the System'speriod of non -operation and the averagemonthly cost of power purchasedunder this Agreement for the preceding twelve 12) months, or for the entire period the System have been in Commercial Operation if lessthan twelve ( 12) months, for the period of time during which the Systemare non -operational.

If an Outageoccursunderthis Sectionand a payment is due from Provider to City, Provider shall include in its next invoice(s) to City (and in the final invoice for any credit owed for the final Contract Year) a credit for the difference between the electricity cost as provided by the Distribution Utility to City for the applicable period.

F. FRESERVED]
G. Change in Conditions. If City requestsan increasein the Solar Facility Output or BatterySystemsOutputdeliveredto theDelivery Point, thePartiesagreeto usegoodfaith efforts to increasesuch capacity and to negotiate such amendmentsto this Agreement as are reasonably necessaryto reflect the economic value of such increasedcapacity. If Provider and City are not able to reach an agreement for such additional Solar Facility Output or Battery Systems Output, City may, atits solediscretion, obtaintheservicesof athird partyfor suchpurposes, providedthat such additional third party provided servicesand any site easementshall not interfere with Provider' s right, title and interest in the System under this Agreement.

H. Performance and Payment Bonds. Provider shall deliver to City evidence that the prime contractor performing the construction and installation services of the Systems maintains payment and performancebonding in favor of the Provider and meeting the following requirements, which shall be provided to the City prior to the commencement of construction on any Site:
a. Performance Bond. A bond issuedby a corporate surety authorized to issuesurety insurancein California, in a form commonly usedfor suchpurposes, in an amount equal to one hundred percent ( 100%) of the Provider' s construction contract price payableunderthecontractsecuringthefaithful performanceof thecontractorof its contract with Provider; and
24 b. Payment Bond. A bond issued by a corporate surety authorized to issue surety insurancein California, in a form commonly used for suchpurposes, in an amount equal to one hundred percent (100%) of Provider' s construction contract payable under the contract securing the payment of all claims for the performance of labor or serviceson, or the furnishing of materials for, the performance of the contract.

All bonds shall be provided by a corporate surety authorized and admitted to transactbusinessin Californiaandshallbein theform providedby City.

I. Provider shall make no alteration to the System after the Commercial Operation Date intendedorreasonablyanticipatedto permanentlyincreasethenameplatecapacity, SolarFacility, or BatterySystemsOutputof theSystemwithoutexpresswrittenapprovalby City. Notwithstandingthe foregoing, ProvidermayaltertheSystem'snameplatecapacityonatemporarybasiswhenperforming maintenanceandrepairactivitiesprovidedthatProviderreturnsthe System's nameplatecapacityto that as of the Effective Date upon the completion of such activities.

12. Metering.

A. Meter. Provider shall provide and maintain standardrevenue grade meters and an electronic data acquisition system at the Delivery Point (each a "Meter", collectively " Meters") to individually measure the actual amount of electricity supplied to City by each of the Solar Facility and the Battery Systemson a continuous basis. Meters shall be installed and maintained at Provider' s sole expenseand shall be located in close proximity to the Delivery Point and in all cases on the Provider side of all Provider owned transformers and other electrical losses.

B. Meter Testing. Provider shall arrange for all Meters to be tested prior to CommercialOperationandonceperyearafterCommercialOperationwithin thirty (30) daysof the anniversary of the Commercial Operation Date. The tests shall be conducted by independent thirdpartieswholarequalified
to conduct such tests. Provider shall bear all costs and expenses associatedwith annual Meter testing. City shall be notified ten (10) Days in advanceof suchtests and shall have a right to be presentduring suchtests. Provider shall provide City with the detailed results of all Meter tests.
i
Inaddition, theMetersshallbeinspectedandtestedforaccuracyatsuchothertimesas City may reasonably request, but in no event more than once every six ( 6) month period. City shallbearthecoshof the additionally requestedMeter testing, unless suchtest showsthat a Meter was inaccurate by more than two percent (2%), in which case the Provider shall bear the Meter testing costs.

I
C. Costof MeterRepair. If theMetertestingdemonstratesthataMeterwasoperating outside of its allowable calibration (+/- 2%), then the Provider will pay for the cost of the repairs, or replacement, necessary to restore a Meter to proper working order. If a Meter is found to be inaccurateby more than two percent (2%), Invoices from the prior six ( 6) months, or from the last time such Meter wasregistering accurately, whichever is less, shall be adjusted in. accordance with Section8, exceptthat City shallnot be obligatedto pay intereston any amountfound to be due becauseMeter was operating outside of its allowable calibration (+/- 2%). Provider shall submit 25 any request for an adjustment to City no later than two ( 2) months after Meter testing had been performed, and City shall not be obligated to pay any adjustment for a prior fiscal year that was not submitted to City within two months after Meter testing was performed. City may withhold payments to Provider if a Meter has registered production in excessof 2% of the Solar Facility Output or Battery SystemsOutput delivered to City and Provider fails to provide City with the appropriate payment pursuant to Section 8 for the amount which City overpaid to Provider as a result of the Meter being outside of the establishedcalibration range.

D. Meter Data. Provider shall gather and maintain the data from a Meter, including but not limited to interval data registered at least once every fifteen ( 15) minutes ( the " Meter Data") and shall make suchMeter Data available to City or maintain theMeter Data suchthat City can accessthe Meter Data remotely through a secureinternet site or such other remote accessas the Parties mutually agree to.

E. Meter Data Audit. City shall have the right to audit the Invoices and/or the Meter Dataoncepercalendaryear. If theauditrevealsthatCity hasbeenoverchargedby morethantwo percent (2%), Provider shall bear the cost of such audit, but in all other casesCity shall bear the cost of such audit.

F. Maintenance of Meter Data. The Parties shall maintain all records related to Invoices andMeter Data for a period of the greater of (i) forty- eight (48) months from the date of such Invoice or Meter Data, or (ii) as otherwise required by law. Such records shall be available for audit as described above.

13. Representations, Warranties and Covenants.

A. Authorization and Enforceability. Each Party representsto the other Party asof the Effective Date that: ( i) such Party is duly organized, validly existing and in good standing under the laws of the state of its formation; ( ii) the execution and delivery by such Party of, and the performance of its obligations under, this Agreement has been duly authorized by all necessary action, doesnot and will not require any further consentor approval of any other Person, and does not contraveneany provision of, or constitute a default under such Party's organizational documents, any indenture, mortgageor othermaterialagreementbinding on suchParty or any valid orderof anycourt, or regulatoryagencyor otherbodyhavingauthorityto which suchParty is subject; and ( iii) this Agreement constitutes the legal and valid obligation of such Party, enforceableagainst such Party in accordancewith its terms, except as may be limited by bankruptcy, reorganization, insolvency, bank moratorium or similar laws relating to or affecting creditors' rights generally and general principles of equity, whether such enforceability is consideredin a proceeding in equity or at law.

B. Insolation. City agrees that access to sunlight (" Insolation") is essential to Provider's ability to providetheprojectedSolarFacility Outputandis a materialinducementto Providerin enteringintothisAgreement. Accordingly, City shallnotpermitanyinterferencewith Insolation available to the System. If City becomesaware of any potential development, foliage or trees, or other activity on adjacent or nearby properties that will diminish the Insolation to the System, City shall adviseProvider of such information andreasonably cooperatewith Provider in 26 reasonablemeasurestaken by Provider in an attempt to preserveexisting levels of Insolation upon the System.

C. Notice of Damage. Each Party shall promptly notify the other Party of any matters it is awareof pertaining to any damageto or loss of the useof the Systemor that could reasonably be expectedto adversely affect the System.

D. Site Owner. The City representsand warrants to Provider that the City is the sole owner of the Site and holds fee title to the Site.

14. Default and Remedies.

A. Events of Default. In the event of a Party' s breach of any performance obligation hereunderor breachof anyrepresentation, warranty, covenant or term of this Agreement, the non - defaulting Party shall provide the defaulting Party with written notice of the default, which notice shall describe the default in reasonable detail. Following the date of receipt of written notice of default, the defaulting Party shall have thirty ( 30) Days to cure any payment default andforty- five 45) daysto cureanyotherbreachor defaultdescribedin thisAgreement; provided, however, that withrespecttonon-paymentdefaults, thecureperiodshallbeextendedbythenumberofdays (not to exceed an additional ninety ( 90) Day period) during which an event of Force Majeure is occurring or during which the defaulting Party has begun corrective action and continues to diligently pursue, !using commercially reasonableefforts, the completion of suchcorrective action.

B. Event of Default. In addition to the foregoing, with respect to a Party, there shall be an event of default ( each an " Event of Default") if:
i
1) solely with respect to the City, the City terminates, amends, suspendsor there is otlierwise a change to the right, title and interest of Provider in the Easement; 2) suchParty fails to timely pay any amount due;
3) suchPartyconcedesin writing to its inability to pay its debtsgenerallyasthey become due;
4) such Party files a petition seekingreorganization or arrangementunder the federal bankruptcy laws or any other applicable law or statute of the United States of America or any State, City or territory thereof,
5) such Party makes an assignment for the benefit of creditors in connection with bankruptcy proceedings;
6) suchPartyconsentsto theappointmentof areceiverof thewholeor anysubstantial part of its assets;
7) such. Party has a petition in bankruptcy filed against it, and such petition is not dismissedwithin sixty ( 60) Days after the filing thereof; i
i
27 8) a court of competentjurisdiction entersan order, judgment, or decreeappointing a receiverof thewholeor anysubstantialpartof suchParty's assets, andsuchorder, judgment or decreeis not vacated or setasideor stayedwithin sixty (60) Days from the date of entry thereof,
9) under the provisions of any other law for the relief or aid of debtors, any court of competent jurisdiction shall assume custody or control of the whole or any substantialpart of suchParty' s assetsand suchcustody or control is not terminated or stayed within sixty ( 60) Days from the date of assumption of such custody or control;
10) such Party ceased its legal existence or ceases doing business or otherwise dissolves; or
11) such Party breachesa material term of this Agreement.

C. Provider Remedies. If an event of default by City under Sections 14(A) or 14(B) has occurred and is continuing, then following the expiration of any applicable cure period, Provider may at its discretion: ( i) suspendperformance under this Agreement, ( ii) seek specific performance from a court of appropriate jurisdiction pursuant, and/ or ( iii) terminate this Agreement, and as Provider' s sole and exclusive remedy in connection with such termination, requireCity to payto Providerasliquidateddamages, andnotasapenalty, theTerminationValue for the System, and any and all amounts then owed Provider for Solar Facility Output or Battery SystemsOutput delivered to City as of the date of such termination pursuant to this Agreement.

In the event of such termination, Provider shall remove the System in accordance with Section 3, at Provider' s sole cost and expense.

D. City Remedies. If an event of default by Provider under Sections 14(A) or 14(B) hasoccurredandis continuing, thenfollowing the expirationof any applicablecureperiod, City may at its discretion: (i) suspendperformanceunder this Agreement, (ii) seekdamagesor specific performancefrom a courtof appropriatejurisdiction, and/or (iii) terminatethis Agreement. In the eventthat City terminatesthis Agreementpursuantto this Section, City may electto either (i) purchasethe Systempursuantto Section9 as of the time of the eventof default; or (ii) require Providerto removethe Systemwithin onehundredeighty (180) DaysatProvider's solecostand expense and restore the Site as required in Section 3.

15. Dispute Resolution.

The Parties agreeto make a good faith attempt to resolve any and all controversies, claims, disagreements, or disputes between the Parties arising out of or related to this. Agreement Dispute"). In the eventof anyDispute, eitherPartymaygive noticeof the disputeto theother Party. In theeventaPartyDisputesall or aportionof aninvoiceor otherpayment, the disputing Partyshalltimely payanyundisputedportionof suchamountdue. ThePartiesshallfirst usegood faith, reasonable, diligent efforts to resolve the dispute within ninety ( 90) Days from the date of such notice. If the Parties do not resolve their dispute within ninety ( 90) Days of notice, then the Partiesmay, upon mutual agreement, submit to mediation before a mutually agreedupon mediator.

In the event the dispute is not resolved through mediation, the Partiesmay pursuetheir legal rights through any other legally permissible means. If a Dispute, or any portion thereof, remains unresolved after applicable dispute resolution requirements, the Provider shall comply with all claims presentation requirements as provided in Chapter 1 (commencing with section 900) and Chapter 2 ( commencing with section 910) of Part 3 of Division 3.6 of Title 1 of Government Code as a condition precedentto the Provider' s right to bring a civil action against City. For purposes of those provisions, the running of the time within which a claim must be presentedto City shall be tolled from the time the Provider submits its written Dispute until the time the Dispute is denied, including any time utilized by any applicable meet and confer process. Pending resolution of the dispute, Providerandits subcontractorsshallcontinueto performthework undertheAgreement and shall not cause a delay of the work during any dispute, claim, negotiation, mediation, or arbitration proceeding, exceptby written agreementof City.

16. Taxes; Liens.

A. Taxes. Provider shall pay any income taxesimposed on Provider dueto the saleof energyunder this Agreement. City shall pay all real property taxes and assessmentsapplicable to the Site. This Agreement may result in the creation of a possessoryinterest (Rev. & Tax. Code § 107. 6). If such a possessory interest is vested in Provider, Provider may be subjected to the payment of personal property taxes levied on such interest in the System. Provider shall be responsible for the payment of, and shall pay before becoming delinquent, all taxes, assessments, fees, or other charges assessed or levied upon Provider, the Project and the System. Provider further agreesto prevent such taxes, assessments, fees, or other chargesfrom giving rise to any lien againstthe Siteor anyimprovementlocatedon or within the Site. Nothing hereincontained shallbedeemedtopreventorprohibit Providerfrom contestingthevalidity or amountof anysuch tax, assessment, or feein themannerauthorizedby law. Providershallberesponsiblefor payment of anypersonalpropertytaxes, possessoryinteresttaxes, permitfees, businesslicensefeesandany andall feesandchargesof anynatureleviedagainsttheSystemandoperationsof Providerat any time. If bills for taxes on the System are received by City, City shall remit such bills to Provider.

B. Liens. Provider shall not directly or indirectly cause, create, incur, assumeor suffer to exist any liens on or with respectto the Site or City' s interest therein. If Provider breachesits obligations under this Section, it shall immediately notify City in writing, shall promptly cause suchlien to be dischargedand releasedof recordwithout cost to City, and shall defendand indemnifyCity againstall costsandexpenses (includingreasonableattorneys' feesandcourtcosts at trial and on appeal) incurred in discharging and releasing such lien.

17. Liability and Indemnity; Insurance.

A. Indemnity. To the fullest extent provided for by law, each Party (" Indemnifying Party") agreesto indemnify, defendandhold harmlessthe other Party, its directors, officers, employees, and agents (each, an " Indemnified Party") from and against any and all claims, whether or not involving a third -party claim, including demands, actions, damages, loss, costs, expenses, and attorney' s fees ( collectively, " Indemnity Claims"), arising out of or resulting from anybreach, negligentact, erroror omissionor intentionalmisconductby the IndemnifyingParty or its trustees, directors, officers, employees, contractors, subcontractors or agents under the terms of thisAgreement; provided, however, thattheIndemnifyingPartywill nothaveanyobligationto indemnifythe IndemnifiedPartyfrom or againstany IndemnityClaimsto the extentcausedby, 29 resulting from, relating to or arising out of the negligence or intentional misconduct of an Indemnified Party or any of its directors, officers, employeesor agents.

If an Indemnified Party determinesthat it is entitled to defenseand indemnification under this Section, suchIndemnified Party shall promptly notify the Indemnifying Party in writing of the Indemnity Claim andprovide all reasonablynecessaryor useful information, and authority to settle and/or defendIndemnity Claim. Defenseandindemnification provided by the Indemnifying Party underthisSectionshallbeprovidedwith legalcounselreasonablyagreedto by theIdentifiedParty.

No settlement that would impose costs or expenseupon the Indemnified Party shall be made without such Parry's written consent.

B. Insurance.
1) Provider Insurance. At all times during the term of the PPA, and any necessary extension thereof for removal of the System from the Site, Provider and all subcontractors, shall obtain, maintain andkeep in full force andeffect the following insurance for coverage of all obligations and associated activities under this Agreement, including but not limited to the use and occupancy of the Site, the businessoperatedby the City thereon, andthe construction, installation, operation, maintenance and repair of the System, in the amounts, and with the conditions required, assetforth herein, provided that the limits setforth herein may be satisfied through a combination of primary and excesspolicies. Each policy required in b)( c)( d) below shall include an additional insured endorsement in favor of City with an additional insured endorsementfor both ongoing and completed operations asit pertainsto (b) andshallincludeanendorsementspecifyingthatsuchcoverage is primary andnon-contributory asto any other coverageavailable to the additional insured. Provider shall, within thirty ( 30) days of the Effective Date of this Agreement and annually thereafter or as requestedby City, provide certificates of insurance and endorsementsdemonstrating compliance with the requirements of this Section.
a. Workers' Compensation Insurance for Provider' s employees to the extent of statutory limits and Occupational Disease and Employer' s Liability Insurance for not lessthan $1,000,000 per occurrence.
b. Commercial General Liability Insurance with a $2,000,000 per occurrence and $5,000,000 aggregatelimit of liability for Bodily Injury, Personal and Advertising Injury and Property Damage Liability, including coverage for Contractual Liability and Products and Completed Operations Liability.

C. Automobile Liability Insurance with limits not less than: Bodily Injury coverage at $2,000,000 each accident, and Property Damage coverage at 2, 000, 000 each accident.
d. Excess Liability Insurancein an aggregateamount of not less than 5,000,000 providing greater limits of insuranceto Provider' s Employer' s Liability, Commercial General Liability and Automobile Liability Insurance which also shall not be more restrictive than coverage provided by thesepolicies.
30 e. Builder' s Risk/ Installation Floater Insurance in a sufficient amount to protect Provider' s property, materials, tools and other financial interests on the Project.
f. Professional Liability Insurance with limits not less than $ 1,000, 000 per claim, with atwo-year tail, solely to the extent andfor suchtime asProvider or any Subcontractor is actively engagedin work with professional liability exposure.
2) City Insurance. City shall maintain and covenantsthat it shall maintain during the Term ( i) insurance sufficient to insure it against loss or destruction of the Site, including lossesoccasionedby operation of the System, and (ii) general liability insurance including bodily injury, property damage, contractual and personal injury. Notwithstanding the foregoing, City reservesthe right to self -insure. 3) Waiver of Subrogation. Provider shall cause each insurance policy obtained by them to include a waiver of subrogation or waiver of the transfer of rights of recovery againstCity by the insurer in connection with any damagecoveredby any policy of Provider. City reserves the right to request copies of any insurer endorsementsthat may be necessaryto affect this waiver of subrogation. 4) Subcontractor Insurance. Provider shall require and verify that all of its subcontractorsmaintain insurancemeeting all of the requirements statedherein.

18. Easement.

City hereby grants to Provider an easementfor the sole purpose of accessto, on, over, underandacrossthe Siteandcontainingall therights necessaryfor Providerto useandoccupy portions of the Site for the purposes of undertaking the work required by Provider under this Agreement, including: installing, constructing, inspecting, operating, owning, maintaining, accessing, repairing, removing and replacing the System, and including ingress and egressrights to the Site for Seller and its employees, contractors and subcontractors and access to electrical panels and conduits to interconnect or disconnectthe Systemwith the Site's electrical wiring ( the Site Easement"). During the period of time between and including the date of the Notice to Proceed and the Commercial Operation Date, the Site Easement shall include, subject to the scheduling andactivity needsof City, the reasonablynecessaryuseof City' s Site for the reasonably necessaryconstruction and installation activities under this Agreement, including, but not limited to, staging areas. City shall haveno liability whatsoeverin connection with property or equipment of Provider or Provider' s contractor( s), subcontractorsor vendors, provided that the City and the City' s employees, affiliates, agents, subcontractors, lessees, licensees and invitees shall not interfere or handle any property (including but not limited to the System) or equipment of Provider or Provider' s contractor( s), subcontractors or vendors without written. authorization from Provider.

The Site Easement term shall commence on the Effective Date and shall continue until the date that is one hundred eighty ( 180) days following the date of expiration or termination of this Agreement. The City hereby covenants that Provider shall have accessto the Site and System during the Site Easementterm. Provider shall notify City prior to enteringthe Site exceptin situationswherethereis imminentrisk of damageto personsor property. City acknowledgesand agreesthat the SiteEasementandotherrights conferredby andthebenefitsandburdensarising 31 under this Section 18 of this Agreement are intended to, and do hereby, constitute covenantsthat run with the land and shall inure to the benefit of andbe binding upon City and its successorsand assignsduring the duration of the Site Easementterm. City agreesto cooperatewith Provider in executing any documentsreasonably requestedby Provider to protect Provider' s rights in or use of the Site, including recording such documentsin the public records.

19. Assignment; Cooperation with Financing.

A. Assignment by Provider. Except asexpresslyprovided in this Agreement, Provider may not sell, transfer, or assign its rights under this Agreement or any right, interest, or obligation therein ( collectively, an " Assignment"), until at least twenty four ( 24) months have expired following the Commercial Operation Date, and only upon the prior written consent of City, which consent may not be unreasonably withheld, conditioned or delayed, provided that any assignee possessesall required skills, knowledge, expertise, experience, and financial capacity and creditworthiness necessaryto perform Provider' s obligations under this Agreement, and assumes in writing the obligations of Provider under this Agreement. Provider shall provide City with no less than sixty ( 60) Days' notice of the request to transfer ownership of the Project. Notice shall identify the party purchasing the Project and provide sufficient detail of the proposed owner for City to evaluate the new owner. Notice shall include, but not be limited to, the following details of the proposed owner: Experience with PPAs and current portfolio; Pasttwo years of financials; Proof of insurance, meeting City requirements and naming City; Confirmation of operations and maintenance provider and outline of operations and maintenance program if different from existing; Details andexampleof annualreport andinvoicing; and Confirmation that all terms under this Agreementandanyrelateddocumentsandagreementswill beperformed. Notwithstanding the foregoing, Provider may, without theprior written consentof City, (i) assign, mortgage, pledge or otherwise collaterally assignits interests in this Agreement to any SecuredParty in connection with any financing for the ownership, acquisition, construction, operation or use of the System as set forth in subsection B, or ( ii) assign its rights, interests and obligations in this Agreement to an affiliate of Provider which is controlled by Provider or under common control with Provider. This Agreement shall be binding on and inure to the benefit of the successorsand permitted assignees.

B. Collateral Assignment by Provider for Financing Purposes. a. In the event Provider assignsits rights under this Agreement as security in connection with any financing transaction entered into by Provider, Provider may mortgage or grant a first priority perfected security interest in this Agreement and the System, and may collaterally assign this Agreement andthe Systemto any mortgageesor holders of security interests, including their successorsor assigns (hereinafter collectively referred to as "Secured Parties"), provided that any such collateral assignmentof this Agreement by Provider shall not release Provider from its obligations or liabilities under this Agreement. City agreesto not unreasonablywithhold, condition or delay its compliance with any reasonablerequestthat City execute any consent, estoppel agreementor other documents related to such financing transaction as may reasonablybe required by such SecuredParties, provided that Provider will reimburse City for the reasonably and documentedlegal fees and costsincurred by suchassignment. 32 C. Assignment by City. Except as otherwise provided in this Agreement, City may assign its rights under this Agreement only upon the prior written consent of Provider, which consent may not be unreasonably withheld, conditioned or delayed; provided that any such assignee ( i) is of equal or greater creditworthiness than City and ( ii) assumes in writing the obligations of City under this Agreement. Notwithstanding the foregoing, City may assign its rights under this Agreement without Provider' s consent to any Person succeeding to all or substantially all of the assetsof City of equal or greater creditworthiness than City, and provided, further, that any such transferee or assigneeassumesin writing the obligations of City under this Agreement.

20. Confidentiality; Publicity.

A. Confidential Information. Any financial, statistical, personal, technical and other data and information relating to a Party' s operationswhich are made available to the other Party in order to carry out this Agreement shall be reasonably protected by such other Party from unauthorizeduse, exceptto the extentthat disclosurethereof is required to comply with applicable law, including but not limited to the California Public Records Act and the Brown Act. The disclosing Party shall identify all confidential data and information at the time it is provided in writing, including by conspicuously marking each such document as " Confidential." Confidentiality does not apply to information, which is known to a receiving Party from other sources, which is otherwise publicly available, or which is required to be disclosed pursuant to an order or requirements of a regulatory body or a court.
1) Confidential Information shall comprise that which Provider identifies as confidential in accordance Applicable Law, including the California Public Records Act, California Government Code § 7920 et seq (" CPRA"), such as, for example only, trade secrets.
2) The Parties agree and acknowledge that this Agreement, and each document incorporated herein, is a public record subject to public disclosure, and shall be publicly disclosed in conjunction with any actions by City' s Governing Board related to approval or ratification hereof, including, without limitation, consideration during a public hearing as required under Government Code section 4217. 12.
3) City shall not be liable to Provider for any disclosure made it its reasonable determination and in good faith compliance with applicable provisions of the CPRA, and Provider will be solely responsible for and shall solely bear all costs andexpensesrelated to or arising from litigation costsif Provider choosesto pursue enforcement of its rights under the CPRA, and shall reimburse City for all reasonable costs and expensesrelated to or arising from litigation related to this Article 20 in which City is reasonably compelled to engage B. Disclosure. Other than under the REC Reporting Rights and except as may be requiredby applicablelaw, includingbut not limited to, the California Public RecordsAct, the Brown Act, or as otherwise identified above, neither Party shall make any disclosure of any 33 designated confidential information related to this Agreement without the specific prior written approval from the other of the content to be disclosed and the form in which it is disclosed, except for such disclosures to the Parties' financing sources, creditors, beneficiaries, partners, members, officers, employees, agents, consultants, attorneys, accountantsand exchangefacilitators asmay be necessaryto permit eachParty to perform its obligations hereunder and asrequired to comply with applicable laws or rules of any exchange upon which a Party' s shares may be traded.

Notwithstanding the foregoing, nothing contained herein shall be deemedto restrict or prohibit City from complying with applicable law regarding disclosure of information, including but not limited to the California Public Records Act and the Brown Act.

C. Publicity. The Parties share a common desire to generate favorable publicity regarding the System and their associationwith it. The Parties agreethat they may, from time to time, issuepressreleasesregarding the Systemand that they shall reasonably cooperatewith each other in connection with the issuanceof suchreleases. Each Party agreesthat it shall not issueany pressreleaseregarding the Systemwithout the prior written approval from the other of the content to be disclosedand the form in which it is disclosed, and eachParty agreesnot to unduly withhold, condition or delay any such approval. In addition, the Parties hereby agreethat (i) the City may publicize that it is serving as a "solar host" for the System; (ii) Provider may publicize that it is serving as the developer, owner and/or operator of the System; and (iii) City, and Provider may display photographs of the System and disclose the nameplate capacity rating of the as -built Systemin its advertising and promotional materials, provided that any suchmaterials identify the City as the solar host, and Provider as the owner, operator and developer, of the System and all information shall be consistentwith this Agreement. Without limitation of the foregoing, Provider agrees to share with City, in digital format, any photographs and other schematics taken by Provider of the Site and the System,. and further agreesthat City may use such photographs and other schematicsfor the purpose of marketing andpromoting their operations.

Nothing herein shall limit in any way, to any extent the right of individual persons, including, without limitation, membersof City' s Governing Board, from exercising their right to free speech in relation to this Agreement and any subject matter hereof, within the constraints of Applicable Law. Nothing herein shall compel either Party to make statementsbeyond its sole, reasonable, good faith discretion.

21. Legal Effect and Status of Agreement.

A.. City Not Operator. Neither City nor any Party related to City shall have the right or be deemed to operate the System for purposes of Section 7701( e)(4)( A)( i) of the Internal Revenue Code.

B. Burdens/ Benefits of System Ownership. Notwithstanding any provision to the contrary under this Agreement, neither City nor anyParty relatedto City shall (i) bearor be deemed to bear any significant financial burden if there is nonperformance by Provider under this Agreement, asthephrase "anysignificantfinancialburdenif thereis nonperformance" is usedin Section7701 (e)(4)(A)( ii) of the Internal RevenueCode; or (ii) be deemedto receive any significant financial benefit if the operating costs of the System are less than the standard of performance and/or operation set forth in this Agreement, as the phrase " significant financial benefit if the 910
operating costsof such facility are lessthan the standardsof performance or operation" is usedin Section 7701( e)( 4)( A)( iii) of the Internal Revenue Code.

C. No Capital Lease: Forward Contract. The Parties acknowledge and agree that for accounting or tax purposes, this Agreement is not and shall not be construedasa capital leaseand, pursuant to Section 7701( e)(3) of the Internal Revenue Code, this Agreement is and shall be treated by eachParty asa service contract for the saleto City of electric energyproduced at analternative energy System. Each of the Parties agrees that it will not dispute that ( i) the transaction contemplatedby this Agreement constitutesa "forward contract" within the meaning of theUnited States Bankruptcy Code and ( ii) each Party is a " forward contract merchant" within the meaning of the United StatesBankruptcy Code.

22. Miscellaneous.

A. Amendments. This Agreement may be amendedonly in a writing signed by both Provider and City or their respective successorsin interest.

B. Notices. Any notice required or permitted to be given in writing under this Agreement shall be mailed by certified mail, postageprepaid, return receipt requested, or sentby overnight courier service, or personally delivered to a representativeof the receiving Party, or sent by facsimile or email (provided an identical notice is also sent simultaneously by mail, overnight courier, or personal delivery as otherwise provided in this Section). All such communications shall be mailed, sentor delivered, addressedto the Party for whom it is intended, at its addressset forth below. A Party may change its addressby providing written notice to the other Party in accordance with this Section.

If to Ci : If to Provider:

City of Fairfield Onyx Development Group LLC
Attention: Public Works/ Utilities Attention: Legal
1000 Webster Street 3rd Floor 505 5thAve, 14thFloor
Fairfield, CA, 94533 New York, NY 10017
Phone: 707- 428- 7485 Email: legal@onyxrenewables. com
Facsimile: 707- 428- 7607
Email: fmu- notices 2fairfield. ca. gov
C. Non - Waiver. The failure, delay or forbearance by either Party to exercise any of its rights or remediesunder this Agreementor to provide written notice of any default to a defaulting Party, will not constitute a waiver of suchrights or remedies. No Party will be deemed to havewaivedany right or remedyunlessit hasmadesuchwaiver specificallyin writing. The waiver by either Party of any default or breachof any term, condition or provision herein contained 35 shall not be deemed to be a waiver of any subsequentbreach of the same term, condition or provision, or any other term, condition or provision contained herein.

D. No Set -Off. Except asotherwise setforth herein, eachParty herebywaives all rights to set -offs of amounts due hereunder. The Parties agree that all amounts due hereunder are independent obligations and shall be made without set- off for other amounts due or owed hereunder.

E. Intellectual Property. Nothing in this Agreement shall be construed to convey to.

City a license or other right to trademarks, copyrights, technology or other intellectual property of Provider.

F. Severability. Shouldanyprovision of this Agreementfor anyreasonbe declared invalid or unenforceableby final andnon_appealableorder of any court or regulatory body having jurisdiction, suchdecisionshallnotaffectthevalidity of theremainingportions, andtheremaining portionsshallremainin full force andeffectasif this Agreementhadbeenexecutedwithout the invalid portion.

G. Survival. Any provision of this Agreement that expressly or by implication comes into or remains in full force following thetermination or expiration of this Agreement shall survive the termination or expiration of this Agreement.

H. Headings. The headings in this Agreement are solely for convenience and easeof reference and shall have no effect in interpreting themeaning. -of any provision of this Agreement.

I. Choice of Law. This Agreement shall be construed in accordance with the laws of the State of California ( without regard to its conflict of laws principles). The venue for any dispute arisingout of or relatingto this Agreementshallbein theCaliforniaCountyin which the System is located.

J. BindingEffect. This Agreement and its rights, privileges, duties and obligations shall inure to the benefit of and be binding upon each of the Parties hereto, together with their respective successorsand permitted assigns.

K. No Partnership. This Agreement is not intended, and shall not be construed, to createanyassociation, joint venture, agencyrelationshipor partnershipbetweenthePartiesor to impose any suchobligation or liability upon either Party. Neither Party shall have any right, power or authority to enterinto any agreementor undertaking for, or act asor be anagentor representative of, or otherwise bind, the other Party.

L. No Third -PartyBeneficiaries. ThisAgreementissolelyfor thebenefitof theParties hereto and no right or causeof action shall accrue by reasonhereof for the benefit of any third party not a party hereto, other than the Indemnitees and any SecuredParties.

M. Counterparts. This Agreement may be executed in counterparts, which shall together constitute one andthe sameagreement. Electronic, facsimile or copies of signaturepages shall have the same force and effect as originals.

N. , Further Assurances. Upon the receipt of a written requestfrom a Party, eachParty shall execute or cause to be executed such additional documents, instruments, estoppels and assurances, and take suchadditional actions, asarereasonablynecessaryanddesirableto carry out the terms and intent hereof, including but not limited to an Interconnection Agreement. Neither Party shall unreasonablywithhold, condition or delay its compliance with any reasonablerequest made pursuant to this Section.

O. Entire Agreement. This instrument and the documents referenced herein represent the full and complete agreement between the Parties hereto with respect to the subject matter contained herein and supersedesall prior written or oral agreementsbetween said Parties with respect to said subject matter.

IN WITNESS WHEREOF, the Parties have executed this Agreement on the Effective Date.

City:

City of
By:

Name:

Title: G
VVY Y` ANArLtim—
PROVIDER:

Onyx Dev pment Group LLC
By: By:

Name: Patricia L. Rollin Name:

Title: Authorized Signatory Title:

PROVIDER NAME]
37 Schedule 1— System and Premises Description
A.. Premises.

Physical Address: Waterman Treatment Plant
Parcel Number: 2900 Vista Grande Circle, Fairfield, CA 95434 Site diagram attached as Attachment A:

Name of Mortgagee ( lender):

Gross acreage of Premises:

Acreage to be used for System:

B. Description of' Solar System
Type:

Solar System Size:

Module:

Inverter:

Mounting System:

OX Yes No
Not Applicable
Refer to Site diagram
Fixed - Tilt Ground Mount Solar PV System
paired with a Battery Energy Storage System
BESS)
1, 785 kW ( DC) ( this is an estimate ( and not a
guarantee) of theSystemsize; Sellermayupdate
the System Size prior to the Commercial
Operation Date.)
The installation consists of ( 3000) QCells,
595W Photovoltaic Modules
Chint SCH275KLT- DO/ US- 800- 36 250W AC
output, UL1741 listed,
grid tied inverters
Fixed - Tilt Terrasmart Racking
The above System Description is based on known conditions as of the Effective Date. The final SystemDescription may vary from the initial description setforth aboveand, following final completion of the System, the above details may be updated to reflect the System Description of the as -built System
38 Exhibit A — Definitions

1. " Annual Production Estimate" shall mean, for the Solar Facility, the estimated energy productionfor a ContractYear assetforth in Exhibit B.

2. " Applicable Law" shall mean, with respect to any person, any law, statute, rule, regulation, ordinance, treaty, order, decree, judgment, decision, holding, injunction, registration, license, guideline, GovernmentalApproval, consentor requirementof any GovernmentalAuthority havingjurisdiction oversuchpersonor its property, asanyof theforegoingmaybe amended from time -to -time, and any corresponding provisions of any successor to the foregoing, together any rules or regulations promulgated under such successor.

3. " Assignment" shall have the meaning asdefined in Section 19(A).

4. " Authorities Having Jurisdiction" shall mean the governmental organization, office or individual responsible for approving equipment, an installation or a procedure.

5. ` Battery Energy Storage System" ( or " Battery Systems") shall meananenergy storagesystem with the minimum nameplatepower and energy capacity as shown in Exhibit F.

6. " Battery SystemsEnergy Shortfall Amount" shall mean an amount equal to the product o£ ( i) theBatterySystemsGuaranteeRate, multiplied by (ii) thenumberof hoursthatonehundred percent ( 100%) of the nameplate power capacity of the Battery Systems was not available during the MeasurementPeriod.

7. " Battery Systems Output" shall mean the total quantity of all actual electrical energy dischargedby the Battery Systemsas measuredin kWhac by a Meter installed in close proximity to theDeliveryPoint. OutputdoesnotincludetheGreenAttributes, Environmental Financial Incentives, RECs or REC Reporting Rights.

8. " BatterySystemsServices" shallmeangeneratingelectricitybill costsavingsfor City through storageanddischargeof electricalenergyon andfrom theBatterySystemsin accordancewith Section 11( B).

9. " Battery Systems Guarantee Rate" means as defined in Exhibit C.

10. " City Conditions Precedent" shall have that meaning as set forth in Section 6(A) of the Agreement.

11. " City Permits" shallhavethatmeaningassetforth in Section5(C) of theAgreement.

12. " Conditions PrecedentDeadline" shall have that meaning as set forth in Section 6(C) of the Agreement.

13. " ContractYear" shallmeanaperiodof twelve (12) consecutivemonths (exceptin thecaseof the first Contract Year which may be longer) with the first Contract Year commencing on the N
Commercial Operation Date and each subsequent Contract Year commencing on the anniversary of the first day of the first month following the Commercial Operation Date.

14. " Commercial Operation" shall mean that (i) the Project is operating and able to produce and deliver Energy to City pursuant to the terms of this Agreement; (ii) Provider has received all local, state and federal Permits and other approvals as may be required by Law for the construction, operation and maintenance of the Project, including approvals, if any, required under the California Environmental Quality Act for the Project and related interconnection facilities.

15. " Commercial Operation Date" shall mean the date on which Provider achieves Commercial Operation for the Project.

16. " Commercial Operation Deadline" shall have that meaning asset forth in Section 6(D) of this Agreement.

17. " Days" shall mean calendar days, unless otherwise specified.

18. " Delay Liquidated Damages" shall mean the daily rate payable by the Provider to City for unexcuseddelays past the Commercial Operation Deadline or if submission of final electrical clearance has not occurred on or before April 14, 2026, in each case as outlined in Section 6( E).

19. " Deliverer" shall meanthe Energy delivery point within Site's electrical systemon City' s side of the Site' s Distribution Utility meter, as designated by the physical interface of the System with the Site' s electrical system.

20. " Distribution Utility" shall meanthe investor owned, public, or private utility or electric utility having jurisdiction over the interconnection of the Systems.

21. " Distribution Utility Upgrades" shall mean that scope of work and associated costs that the Distribution Utility requires on the Distribution Utility side of the Distribution Utility meter in order for the Systemto interconnect to the Distribution Utility system.

22. " Energy" shall mean electrical energy measuredin kWhac.

23. " Energy Shortfall Amount" shall mean an amount equal to the product of. ( i) the Output Guarantee Rate, multiplied by ( ii) the difference between the delivered Output for such Measurement Period and the Output Guarantee for such Measurement Period.

24. " EnvironmentalFinancialIncentives" shallmeaneachof the following financialrebatesand incentives that is in effect as of the Effective Date: ( i) investment tax credits associated with the development, construction, ownership or operationof the System, accelerateddepreciation, and other financial incentives in the form of credits, reductions or allowances associated with the System that may be applied to reduce any stateor federal income taxation obligation, and ii) the right to claim federal income tax credits under Sections 26 or 48 of the Internal Revenue 41 Code or any state tax law or income tax deductions with respect to the System under the Internal RevenueCode or any statetax law. Environmental Financial Incentives do not include Green Attributes.

25. " Expiration Date" shall mean the last day of the month that follows the twenty-fifth '( 25th) annual anniversary of the Commercial Operation Date.

26. " Force Majeure" shall mean any event or circumstancesbeyond the reasonablecontrol of and without the fault or negligenceof theParty,claiming ForceMajeure, which cannotreasonablybe avoided, mitigated or cured through the reasonableand diligent efforts of the Party claiming Force Majeure. It shall include, without limitation, interruption or delay of the construction of the Systemor failure or interruption of the production, delivery or acceptanceof electricity due to: ( i) natural phenomena, suchasstorms, hurricanes, floods, lightning, volcanic eruptions and earthquakes; ( ii) explosions or fires arising from lightning or other causesunrelated to the acts or omissions of the Party seeking to be excusedfrom performance; (iii) acts of war or public disorders, civil disturbances or riots, insurrection, sabotage, epidemic, terrorist acts, or rebellion; ( iv) action by a Governmental Authority resulting in a moratorium on the activities related to this Agreement; and (v) the inability of one of the Parties, despite its reasonable efforts, to obtain, in a timely manner, any Permit necessaryto enable the affected Party to fulfill its obligations in accordance with this Agreement, provided that the delay or non - obtaining of such Permit is not attributable to the Party in question and that such Party has exercised due diligence to obtain such Permit. Force Majeure will not be basedon (i) City' s inability to use Energy purchased hereunder, (ii) Provider' s ability to sell Energy at a price greaterthan the price of Energy under this Agreement, or (iii) City' s voluntary or involuntary shuttingdownor closingof thefacilitieslocatedattheProperty. Economichardshipof either Party shall not constitute Force Majeure.

27. " Governmental Authofity" shall mean the government of the United States of America, any other nation or any political subdivision thereof, whether state or local, and any agency, authority, instrumentality, regulatorybody, court, central bank or other entity exercising executive, legislative, judicial, taxing, regulatory or administrative powers or functions of or pertaining to government ( including any supra -national body exercising such powers or functions, such as the European Union or the European Central Bank).

28. " Governmental Approvals" shall mean any notices to, reports or other filings to be made with, or any, consents, registrations, permits or authorizations to be obtained from, any Governmental Authority.

29. " Green Attributes" shall mean any and all credits, benefits, emissionsreductions, offsets and allowances, howsoeverentitled, attributableto thegenerationof Outputfrom the System, and its displacement of conventional energy generation, that is in effect asof the Effective Date or may come into effect in the future. Green Attributes include but arenot limited to Renewable Energy Certificates, aswell as: ( i) any avoided emissionsof pollutants to the air, soil or water such as sulfur oxides ( SOx), nitrogen oxides ( NOx), carbon monoxide ( CO) and other pollutants; ( ii) any avoided emissionsof carbondioxide (CO2), methane (CH4), nitrous oxide, hydrofluorocarbons, perfluorocarbons, sulfur hexafluoride and other greenhouse gases 42 GHGs) that have beendetermined by the United Nations Intergovernmental Panel on Climate Change, or otherwise by law, to contribute to the actual or potential threat of altering the Earth' s climate by trapping heat in the atmosphere; and (iii) the reporting rights to these avoided emissions, such as REC Reporting Rights. Green Attributes do not include ( i) any energy, capacity, reliability or other power attributes from the System, (ii) Environmental Financial Incentives, ( iii) fuel -related subsidiesor "tipping fees" that may be paid to Provider to accept certain fuels, or local subsidies received by the generator for the destruction of particular preexisting pollutants or the promotion of local environmental benefits or ( iv) emission reduction credits encumberedor usedby the Systemfor compliance with local, state or federal operating and/or air quality Permits.

30. " Hazardous Materials" means any hazardousor toxic material, substanceor waste, including petroleum, petroleum hydrocarbonsor petroleum products, petroleum by-products, radioactive materials, asbestosor asbestos -containing materials, gasoline, diesel fuel, pesticides, radon, urea formaldehyde, mold, lead or lead -containing materials, polychlorinated biphenyls; and any other chemicals, materials, substancesor wastesin any amount or concentration which are regulated under or for which liability can be imposedunder any Applicable Law.

31. " Insolation" shallmeantheamountof solarenergymeasuredin wattspersquaremeter (W/mz) falling on a particular location during a specific time, aspublished by the National Renewable Energy Laboratory.

32. " Interconnection Agreement" shall mean an agreemententeredinto by and between Cityandthe DistributionUtility which. agreementshall providefor ( i) eachSystemto beinterconnectedwith the DistributionUtility' s electricitydistributionsystem, ( ii) forenergyto flowfrom each System to suchsystemand ( iii) for energyto flowfrom such systemto theSite, as applicable, under the provisionsof all applicableDistributionUtility' s tariffs. 33. " InternalRevenue Code" shall mean the InternalRevenue Code of 1986, as amended. 34. " kWac" shall meankilowattalternatingcurrent. 35. "
kWdc" shall mean kilowattdirect current. 36. '
Whac" shall meankilowatt-hour alternatingcurrent. 37. " Noticeto Proceed" shall mean as definedin Section6( C). 38. " Outage" shall mean as definedin Section4( F) 39. "
Output" or " SolarFacilityOutput" shall meanthe totalquantityof all actualelectricalpower generated by theSolarFacilitiesas measuredby a Meterin closeproximityto theDeliveryPoint measuredin kWhac. Output does not includethe GreenAttributes, Environmental Financial Incentives, RECs or RECReportingRights. 40. "
OutputGuaranteeRate" shall mean as definedin ExhibitB. 43

41. " Parallel Energy Services" shall meanto remain interconnected to and receive grid services.

42. " Permits" shall mean all government permits and approvals, regulatory or otherwise required for the construction, installation, completion and operation of the System.

43. " Person" shall mean any individual, corporation, partnership, joint venture, association, joint stock company, trust, trustee, estate, limited liability company, unincorporated organization, real estateinvestment trust, government or any agency or political subdivision thereof, or any other form of entity.

44. " Power Price" shall meanthe per kWhac rate(s) as setforth on Exhibit B

45. " Project" shall have that meaning asset forth in the Recitals of this Agreement.

46. " Provider Conditions Precedent" shall have that meaning as set forth in Section 6(B) of the Agreement.

47. " Provider Permits" shall havethat meaning assetforth in Section 5(C) of the Agreement.

48. " RECs" or "RenewableEnergy Certificates" shall mean renewable energy certificates related to andrepresentingGreenAttributes (alsoknown asgreentags, renewableenergycredits, or tradable renewable certificates), which are tradable environmental commodities in the United States and represent 1 megawatt - hour ( MWh) of electricity generated from an eligible renewable energy resource. These certificates can be sold and traded and the owner of the REC can claim to have purchasedrenewable energy.

49. " REC Reporting Rights" shall mean the right of a REC purchaserto report the ownership of accumulated RECs in compliance with federal or state law, if applicable, and to a federal or state agency or any other Party at the REC purchaser's discretion, and include without limitation those REC Reporting Rights accruing under Section 1605(b) of the Energy Policy Act of 1992 and any present or future federal, state, or local law, regulation or bill, and international or foreign emissions trading program.

50. " Supervisory Control and Data Acquisition" or " SCADA" shall mean the system that monitors, communicates with, and controls devices throughout the System.

51. " Site" shall mean the portion of City' s real property on which a System is to be located pursuant to this Agreement, as describedin Schedule 1 attachedhereto.

52. " Solar Facility" means each solar photovoltaic generation plant, together with all necessary inverters, ancillary equipment with a target installation size expressedin kWdc and Mac as shown in Exhibit F to be installed at the Site and as described in Schedule 1 attached hereto.

53. " Termination Value" shall equal the amount shown in Exhibit D for each Contract Year.

Exhibit B - Power Price and Output Guarantee Rate
11 10% ITC Adder Scenario
Contract
Period,
Months
Contract
year
Power Price
Annual
Production
Estimate
kWh
Output Guarantee
Rate
1- 12 1 0. 121 kWh Grace period
13- 24 2 0. 121 kWh 3, 050, 675 0. 027 kWh
25- 36 3 0. 121 kWh 3, 035, 422 0. 027 kWh
37- 48 4 0. 121 kWh 35020, 245 0. 027 kWh
49- 60 5 0. 121 kWh 3, 005, 144 0. 027 kWh
61- 72 6 0. 121 kWh 2, 990, 118 0. 027 kWh
73- 84 7 0. 121 kWh 2, 975, 167 0. 027 kWh
85- 96 8 0. 121 kWh 2, 960, 291 0. 027 kWh
97- 108 9 0. 121 kWh 2, 945, 490 0. 027 kWh
109- 120 10 0. 121 kWh 2, 930, 762 0. 027 kWh
121- 132 11 0. 121 kWh 2, 916, 109 0. 027 kWh
133- 144 12 0. 121 kWh 2, 901, 528 0. 027 kWh
145- 156 13 0. 121 kWh 2, 887, 020 0. 027 kWh
157- 168 14 0. 121 kWh 2, 872, 585 0. 027 kWh
169- 180 15 0. 121 kWh 2, 858, 222 0. 027 kWh
181- 192 16 0. 121 kWh 2, 843, 931 0. 027 kWh
193- 204 17 0. 121 kWh 2, 829, 712 0. 027 kWh
205- 216 18 0. 121 kWh 2, 815, 563 0. 027 kWh
217- 228 19 0. 121 kWh 2, 801, 485 0. 027 kWh
229- 240 20 0. 121 kWh 2, 787, 478 0. 027 kWh
241- 252 21 0. 121 kWh 2, 773, 540 0. 027 kWh
253- 264 22 0. 121 kWh 2, 759, 673 0. 027 kWh
265- 276 23 0. 121 kWh 2, 745, 874 0. 027 kWh
277- 288 24 0. 121 kWh 2, 732, 145 0. 027 kWh
289- 300 25 0. 121 kWh 2, 718, 484 0. 027 kWh
21 Standard 30% ITC Scenario
Contract
Annual
Period,
Contract
Power Price
Production Output Guarantee
year Estimate Rate
Months kWh)
1- 12 1 0. 1416 kWh Graceperiod
13- 24 2 0. 1416 kWh 3, 050, 675 0. 027 kWh
25- 36 3 0. 1416 kWh 3, 035, 422 0. 027 kWh
37- 48 4 0. 1416 kWh 3, 020, 245 0. 027 kWh
49- 60 5 0. 1416 kWh 3, 005, 144 0. 027 kWh
61- 72 6 0. 1416 kWh 2, 990, 118 0. 027 kWh
73- 84 7 0. 1416 kWh 2, 975, 167 0. 027 kWh
85- 96 8 0. 1416 kWh 2, 960, 291 0. 027 kWh
97- 108 9 0. 1416 kWh 2, 945, 490 0. 027 kWh
109- 120 10 0. 1416 kWh 2, 930, 762 0. 027 kWh
121- 132 11 0. 1416 kWh 2, 916, 109 0. 027 kWh
133- 144 12 0. 1416 kWh 2, 901, 528 0. 027 kWh
145- 156 13 0. 1416 kWh 2, 887, 020 0. 027 kWh
157- 168 14 0. 1416 kWh 2, 872, 585 0. 027 kWh
169- 180 15 0. 1416 kWh 2, 858, 222 0. 027 kWh
181- 192 16 0. 1416 kWh 2, 843, 931 0. 027 kWh
193- 204 17 0. 1416 kWh 2, 829, 712 0. 027 kWh
205- 216 18 0. 1416 kWh 2, 815, 563 0. 027 kWh
217- 228 19 0. 1416 kWh 2, 801, 485 0. 027 kWh
229- 240 20 0. 1416 kWh 2, 787, 478 0. 027 kWh
241- 252 21 0. 1416 kWh 2, 773, 540 0. 027 kWh
253- 264 22 0. 1416 kWh 2, 759, 673 0. 027 kWh
265- 276 23 0. 1416 kWh 2, 745, 874 0. 027 kWh
277- 288 24 0. 1416 kWh 2, 732, 145 0. 027 kWh
289- 300 25 0. 1416 kWh 2, 718, 484 0. 027 kWh
The Power Price set forth in Exhibit B( 1) and ( 2) includes consideration for reimbursement of Development Costs in the amount of $ 385, 000.

The City shall, at the City' s sole cost and expense, install a new service transformer in connection with the Distribution Utility Upgradesasper the SupplementalReview of the Interconnection Agreement for the High Lift upgradeproject (PM435228024) with an estimated cost to be paid to the Distribution Utility of $213,528 (the "Transformer Cost"). The City shall reimburse Provider, at cost, for any amounts paid by Provider to the Distribution Utility for the Transformer Cost.

Provider assumedthat the total cost to be paid to the Distribution Utility in connection with theDistributionUtility Upgradeswould be $4,000. If theactualcostreasonablyincurredby Provider for Distribution Utility Upgrades exceeds $4,000, then Provider shall be entitled to a proportionate increase of the Power Price in an amount of $ 0.0005/ kWh for each additional 10,000 increasein cost. If the actual cost reasonablyincurred by Provider for Distribution Utility Upgradesis less than $4,000, City shall be entitled to a proportionate decreaseof the Power Price in an amount of $0.0005/kWh per $10,000 decreasein cost. Provider shall work diligently with City to minimizethecostsfor DistributionUtility Upgradesat all pointsof the Project.

The Power Price set forth in this Exhibit B is based on certain assumptions set forth in Section 4(C) of the Agreement, and the Parties acknowledge that the Power Price may, if ( and only if) the assumptions provided in Section 4(C) are inaccurate, require an adjustment. Provider 47 shall deliver to City reasonableevidence of any increasesin cost incurred by Provider to re -design, construct, install or maintain the Systemasa result of suchassumptionsbeing inaccurate, provided that City andProvider acknowledge and agreethat an executedchangeorder delivered by Provider to a contractor or subcontractor shall constitute reasonable evidence of such cost increase. The Power Price shall be adjusted as follows:

1. If suchcost increaseis due to unforeseenconditions or groundwork at the Site including but not limited to excavation/circumvention of underground obstacles), and such cost increases were not mitigated by the City, then Provider shall be entitled to aproportionate increaseof the Power Price in an amount of $ 0. 0005/ kWh for each additional $ 10, 000 increase in cost.

2. If Hazardous Substances are discovered at the Site, and such cost increases were not mitigated by the City, then Provider shall be entitled to a proportionate increase of the Power Price in an amount of $0.0005/kWh for each additional $ 10, 000 increase in cost to Provider to re - design, construct, install or maintain the System.

3. If such cost increase is due to the failure by City to obtain the City Permits by September30, 2024, assumingtimely delivery of documentsneededfrom the Providerto theCity asagreeduponin theprojectschedule, thenProvidershall be entitled to a proportionate increase of the Power Price in an amount of

0. 0005/ kWh for each additional $ 10, 000 increase in cost to Provider to redesign, construct, install or maintain the System.

4. If suchcost increaseis due to the inaccuracy of any information provided by City and relied upon by Provider, then Provider shall be entitled to a proportionate increase of the Power Price in an amount of $ 0.0005/kWh for each additional $ 10, 000 increase in cost to Provider to re - design, construct, install or maintain the System.

Exhibit C — Battery Systems Guarantee Rate
Contract
Period,
Months
Contract
Year
Guaranteed
Cycles Battery Systems Guarantee Rate
1- 12 1 296 53 cycle
13- 24 2 282 53 cycle
25- 36 3 274 53 cycle
37- 48 4 269 53 cycle
49- 60 5 264 53 cycle
61- 72 6 259 53 cycle
73- 84 7 256 53 cycle
85- 96 8 252 53 cycle
97- 108 9 248 53 cycle
109- 120 10 245 53 cycle
ME
Exhibit D — Termination Values
Contract Period,
Months
Contract Year Termination Value
1- 12 1 10, 986, 736. 61
13- 24 2 9, 749, 821. 45
25- 3 6 3 8, 293, 035. 51
37- 48 4 7, 030, 421. 31
49- 60 5 5, 881, 460. 65
61- 72 6 4, 721, 702. 17
73- 84 7 4, 457, 828. 16
85- 96 8 4, 283, 377. 04
97- 108 9 4, 102, 748. 09
109- 120 10 3, 917, 604. 01
121- 132 11 3, 726, 796. 12
133- 144 12 3, 530, 089. 17
145- 156 13 3, 326, 298. 28
157- 168 14 3, 117, 011. 97
169- 180 15 2, 901, 061. 60
181- 192 16 2, 678, 172. 06
193- 204 17 2, 447, 135. 70
205- 216 18 2, 209, 461. 38
217- 228 19 1, 963, 953. 59
229- 240 20 1, 710, 290. 60
241- 252 21 1, 447, 234. 60
253- 264 22 1, 177, 069. 30
265- 276 23 897, 737. 65
277- 288 24 608, 864. 82
289- 300 25 309, 175. 61
50 Exhibit E — Project Development ScopeResponsibility
City of Fairfield Permits and Project
Development Scope
Provider Permits and Project Development
Scope
Building, zoning, electrical Geotech
CEQA Exemption SWPPP
Title/ Deed for Ownership Civil Engineering
51 Exhibit F — General Conditions and Technical Specifications ATTACHED BEHIND THIS COVER PAGE]

GENERAL CONDITIONS AND TECHNICAL SPECIFICATIONS
Table of Contents
GENERAL CONDITIONS AND TECHNICAL SPECIFICATIONS................................................................... I l. PROJECT OVERVIEW................................................................................................................................... 2

2. GENERAL REQUIREMENTS........................................................................................................................ 2

3. ENGINEERING AND DESIGN REQUIREMENTS....................................................................................... 9

4. EQUIPMENT................................................................................................................................................. 18

5. COMMUNICATIONS AND MONITORING SYSTEMS............................................................................. 23

6. CONSTRUCTION......................................................................................................................................... 26

7. FINAL PROJECT CLOSEOUT..................................................................................................................... 32

8. OPERATIONS AND MAINTENANCE........................................................................................................ 34 ATTACHMENT A - PRELIMINARY ENGINEERING DESIGN PACKAGE..................................................... 35 ATTACHMENT B - SITE ASSESSMENT TABLE............................................................................................... 36 ATTACHMENT C - PROJECT SCHEDULE......................................................................................................... 37 ATTACHMENT D - COMMISSIONING SCHEDULE......................................................................................... 38 ATTACHMENT E - OPERATIONAL OBJECTIVES.......................................................................................... 39 ATTACHMENT F - MAJOR EQUIPMENT.......................................................................................................... 40

1. PROJECT OVERVIEW
Installer shall be solely responsible for all work required to complete the Project including but not limited to: ( a) project management including design, engineering, submittals, construction, interconnection, commissioning and Distribution Utility sign off, ( b) procurement of all materials and equipment; (c) design and engineering including civil, structural, electrical, seismic and wind loading requirements and fire protection requirements; ( d) permitting and environmental compliance with the current version of all applicable codes and standards; ( e) Distribution Utility interconnection requirements compliance; ( f) site preparations including but not limited to grubbing, clearing, grading, roads, dust control, drainage requirements, construction wastewater and storm water disposal, removing excess debris, all final site preparation, and all other requirements set forth in the Agreement; ( g) meters, monitoring, and SCADA system and weather station; ( h) production analysis and performance guarantee for the Systems; (i) conformance to manufacturers' installation requirements and warranty terms; 0) acceptance testing, commissioning, interconnection signoff and Permission to Operate by the Distribution Utility; ( k) construction closeout including punch list, as -built drawings and documents package, site cleanup, and cleaning of the Systems; ( 1) operation and maintenance, if required in the Agreement ( m) site security requirements; ( n) safety plans and measures per Site Host approval. In addition to these general responsibilities, Installer shall be responsible for all additional requirements as set forth in the Agreement and all exhibits and attachments, including but not limited to this General Conditions and Technical Specifications.

Installer shall also be responsible for providing Site Host with copies of relevant Operations and Maintenance manuals, testing reports, start-up procedures, warranties, guarantees, and commissioning reports corresponding to the work. Installer shall executeall of its obligations in amanner which reasonably minimizes interference and inconvenience to Site Host. Installer shall regularly report status of Installer' s execution of its obligations under the Agreement to Site Host.

2. GENERAL REQUIREMENTS
Project Management
Installer shall act as the general contractor and is responsible for overall safety on each Project Site.

Installer shall conduct all project management activities required to complete the Project, including coordination efforts with Site Host' s representative, the Distribution Utility, inspectors, permitting agencies, suppliers, subcontractors, Installer' s office, field Project staff and any other third parties that are involved in or impacted by the Project. The installation must be "turn -key," requiring a minimum level of supervision and project managementby the Site Host, including all materials, equipment and labor, completed and commissioned per the specifications and general conditions contained herein. All Distribution Utility related interconnection work, fees, and installations necessaryto make the Systems operational will be the sole responsibility of the Installer in accordancewith any requirements of the Distribution Utility.

Project Schedule
Installer will develop, with input from Site Host, a Project Schedule using Microsoft® Project or equivalent and submit the Project Scheduleto Site Host. Site Host will establish a weekly construction meeting at which time the work of the previous week will be reviewed, and a three-week look -ahead schedule will be coordinated. The three- week look - ahead schedule shall be created in MS Excel® or equivalent and present the list of activities occurring at each Site on a daily basis. 2 The work on the Project shall be completed on or before the Commercial Operation Deadline in accordancewith the Project Schedule set forth below and asmay be reasonably amendedfrom time to time during the Agreement Term but in no caseextending beyond the Commercial Operation Deadline.

The Project Schedule shall only be modified upon the written approval of Site Host. Any modified scheduleapproved by Site Host shall replace the existing Project Schedule setforth below.

Deadlines dictated by any and all incentive programs, including the Investment Tax Credit, must be accounted for in the Project Schedule.

The Project Scheduleshall include, at a minimum, the following milestones and shall become a part of the Agreement upon approval of Site Host:

Milestone
50% drawings due to Site Host
90% drawings due to Site Host
100% drawings due to Site Host
Site Host review of 50% drawings
Site Host review of 90% drawings
Site Host review of 100% drawings
Permit Approval
Major Equipment Order Date
Site Preparation Start
Site Preparation Completion
Construction Start
Electrical & Mechanical Completion
Interconnection Sign - off
Testing & Commissioning Completion
Utility Meter and Rate Switch Submittal
Permission to Operate Date
Commercial Operation Date
Commercial Operation Deadline
Final Project Completion Date
The Project Schedule shall indicate the beginning and completion dates of all phasesof construction and shall use the critical path method for the planning and scheduling of all work required. The schedule will separately identify those milestones or events that must be completed before other portions of the work can be accomplished. The Project Schedule shall incorporate float for inclement weather andresulting muddy site conditions dueto rain andshall also include any potential acceleration paths. Scheduled float for non -working rain -related days and resulting muddy site conditions shall be based upon the latest and nearest available data from acceptable data issued from the National Weather Service.

A monthly project schedule update shall be provided to accurately indicate the actual progress of the work against the baseline Project Schedulefor the prior month, and the remaining planned completion of the work.

The scheduling is necessaryfor Site Host' s adequatemonitoring of the progress of the work. Site Host may disapprove such a scheduleandrequire modification to it if, in the opinion of Site Host, adherence to the progress schedule will causethe work not to be completed in accordancewith the Agreement.

Installer shall adhereto any such modifications required by Site Host. Between the monthly schedule updates, it is the obligation of Installer to monitor the progress of the work against the current construction scheduleactivities, andto notify Site Host in writing of all changedactivity start datesand finish dates.

Installer will exchange scheduling information with subcontractors and suppliers. Installer will order work, equipment and materials with sufficient lead time to avoid interruption of the work.

Installer shall also, if requestedby Site Host, provide revised scheduleswithin fifteen ( 15) days if, at any time, Site Host considersthe CommercialOperationDeadlineto be in jeopardy. The revised schedule shall be designed to show how Installer intends to accomplish the work to meet the original Commercial Operation Deadline. The form and method employed by Installer shall be the sameas for the original progress schedule. Installer shall modify any portions of the schedule that become infeasible becauseof " activities behind schedule" or for any other valid reason. Installer will provide documents and justification for any schedule changes. An activity that cannot be completed by its original Commercial Operation Deadline shall be deemed to be behind schedule.

IF INSTALLER SUBMITS A REVISED SCHEDULE SHOWING AN EARLIER COMMERCIAL

OPERATION DATE FOR THE PROJECT, SITE HOST' S ACCEPTANCE OF THIS REVISED

SCHEDULE SHALL NOT ENTITLE INSTALLER TO ANY ADDITIONAL COMPENSATION OR CLAIM DUE TO ANY SUCH REVISED SCHEDULE UNLESS OTHERWISE AGREED.

Site Host Project Objectives
Site Host requires that Installer perform eachof the following in accordancewith the Agreement:

A. Prepare and submit all relevant incentive and funding applications on a timely manner to provide the best opportunity for the Project Sites to receive incentives and funding.

B. Ensure that construction activities and Project installation and operation are performed safely, comply with all applicable laws, and do not result in any adverseeffect on Site Host staff, surroundingpersonsandproperty, existingfacilities, local powerquality, local data systemsor daily operations at any Project Site throughout the life cycle of the installation.

Manage construction and operation activities so that they minimally disrupt the calendar of operations at each Project Site.

C. Define a scope of work and create a schedule for the Project and manage the entire Project, including but not limited to contracts, design, engineering, permitting, approvals, procurement, pre -construction, Distribution Utility interconnection, installation, testing, and commissioning. Ensure work is completed when neededto meet Project deadlines.

D. Design and implement the Systemsto obtain maximum projected net savings andcashflow over the term of the Agreement using proven technology that complies with the terms and conditions of the Agreement and complies with all relevant codes and regulations.

E. Design and implement the Systems as defined in the Site Assessment Table and conceptually defined in the Preliminary Engineering Design Package.

F. Design and implement the Systems to meet the Operational Objectives. 4 G. Design and implement the Systems sized in compliance with the Distribution Utility' s applicable rate structure, energy consumption, and load profiles for eachProject Site, and in compliance with all applicable Distribution Utility requirements. Ensure that all Systems aredesigned and installed mitigate the need for Distribution Utility upgrades and facilitate ensuring that such costsare minimized throughout the entire Project.

H. Ensure that the Project meets all financial and environmental incentive requirements and deadlines.

I. Ensure that all Project design and construction activities are coordinated with Site Host operations and/ or construction activities and are in compliance with written work rules, safety requirements, and specifications provided by the Site Host at all times.

Communication Protocol
Throughout the entire Project timeline, the representativeselectedby Site Host will be Installer' s main source of contact regarding any and all Project related issues. At all times, Installer shall include Site Host' s representative in all communications with the Site Host.

Unless otherwise statedin the Agreement and subject to changeby the Site Host, the Parties shall meet once every two weeks during the design phaseof the Project and weekly during the construction phase of the Project to, among other things, review work performed to date and to be performed. Installer shall organize the meeting, prepare, and distribute meeting notes. Meeting minutes shall be based on a mutually agreedto meeting minutes template, andshall include a three-week look -aheadschedule, request for information log, change order log and submittals log with three week look -ahead priority list. Meeting minutes shall be updatedduring the meeting anddistributed at the endof the meeting. Site Host shall have five businessdays after receipt of suchminutes to object to them in writing and provide corrections in writing. A quorum of meeting attendeeswill be named at the first meeting but may be modified as necessary by the Site Host. The named quorum shall be in attendance at all Project meetings. A pre -construction meeting shall be held prior to any work being performed on the site with all required parties.

Sizing of the Systems
Installer is responsible for the sizing of the Systems to meet the Operational Objectives of the Project at each Site.

Incentives
Unless specifically stated otherwise in other Agreement, Installer shall prepare and submit to all applicable agencies, on behalf of Site Host, or assist Site Host in doing so directly, all applications, proof of progress submittals, and claim forms and documentation necessaryfor any environmental or financial incentives and rebates, provided that Site Host shall have the opportunity to review, comment on, and approve all such applications and documentation prior to submission by Installer. If the Site Host decides to prepare and submit such documents, Installer will coordinate and provide Site Host promptly upon Site Host' s written request all documents reasonably necessaryfor Site Host to do so.

Installer shall not charge any additional fee for its services. Unless statedotherwise in other Agreement, Site Host shall pay for all fees required to file the applications. All rebates or incentives available in connection with the Systemsare owned by the Site Host.

Physical Site Investigation & Project Feasibility Assessment Installer shall read and becomeknowledgeable with all documentation available concerning the Project and visit the Sites to assessits conditions and logistics, including but not limited to all Distribution Utility interconnection related requirements. Installer shall conduct feasibility and configuration assessments, environmental assessments, and all other inspections of the Sites to determine that the Sites can support the installation and interconnection of the Systems. Installer must visit the Sites to ascertain site conditions, accuracy of provided drawings and feasibility of design. Installer shall be soleresponsible to ensure that each Site' s soil conditions and terrains are favorable for the Project.

Although Site Host may provide historical information regarding the Sites, Site Host makes no representationasto the accuracyof the information about the Sitesprovided in the requestfor proposals package or otherwise, including data, drawings and reports developed by third parties. Except as otherwise provided in the Agreement with respectto information provided by Site Host, Installer shall rely solely on its own due diligence to discover and confirm existing conditions at the Sites. However, Installer shall not be liable for hidden or latent defects in the site conditions. Installer shall report any discovered and previously unknown site conditions of a substantial nature to Site Host within five ( 5) days of discovery.

Installer shall be solely responsible for ensuring the existing electrical distribution equipment at the Sits, including but not limited to the main service switchgear and Distribution Utility transformer, will support the interconnection of the Systems. Installer is responsible for all scope, costs and designs relating to upgradesto the existing electrical systemrequired to accommodatethe Systems installation and interconnection, and has included these upgrades in its scope, costs and design drawings.

Installer shall confirm that the Systems will be interconnected to the correct meter at each Site by validating the meter and service account identification numbers ("SAID") with the Distribution Utility.

Installer is responsible for any upgradesto the existing structuresand/or structural blocking required to accommodatethe loads imposed and mechanical attachmentsrequired by the Systemsandhasincluded those changes in their scope, costs and design drawings.

Site Host operatesunder several environmental permits issued by various agencies. To the extent that Site Host has provided such a permit to Installer in advance of the Effective Date of the Agreement, and dueto an action, inaction, or negligence by Installer, Site Host becomessubject to non-compliance penalties, the cost of suchpenalties shall be borne by Installer.

Installer shall identify if any third -party site assessmentsare required and be responsible for obtaining all required studies at their sole cost and expense. Installer shall assume any and all costs and risks associatedwith physical Site conditions, real estate constraints and environmental site assessmentas mutually agreed between the parties. Reports which may be required to be obtained by Installer at Installer' sjudgment ( unless otherwise noted below) and at the Installer' s sole cost include, but arenot limited to:

Structural Report
Geotechnical Report
Title Reports and/ or American Land Title Association (" ALTA") Surveys Boundary Surveys
Topographic Surveys
Underground Utility Survey
Glint and Glare Study ( where applicable)
Arc Flash Study / Coordination Study
Site Electrical Service Assessments
Environmental Studies
These reports must be obtained when requestedby Site Host or any other Governmental Authority having jurisdiction.

Permitting, Codes, Regulatory Compliance
Installer shall obtain, oversee and adhere to all required permissions for Project construction and operation by obtaining approvals from all Governmental Authority having jurisdiction over the Project, including, but not limited to the Distribution Utility, incentive authorities, the California Energy Commission (" CEC"), fire safety, California Occupational Safety and Health Administration (" Cal OSHA"), right- of-way permits, easementagreementsand other codesand best practices. Specifically, Installer shall obtain and submit all documents to achieve and maintain Permission to Operate with all required Governmental Authorities. In addition to stampedand approved plans, Installer shall provide Site Host with installation compliance confirmation letters from all authorities having jurisdiction within five ( 5) days of receipt.

In addition, for Sites on public schools, Installer shall be solely responsible for ensuring that the System is constructed in compliance with all applicable laws, regulations, and in accordance with the standards set by any governmental program providing funding for the System, including, but not limited to, where applicable all permits and approvals required by the Division of the State Architect (" DSA") in any way related to the design, installation, construction and operation of the Systems, including but not limited to any exterior improvements and/ or exterior upgrades the DSA may require of the Provider in order for the Systems to comply the Field Act ( Education Code 4417280- 17317) and American with Disabilities Act (" ADA"). Compliance with The California Environmental Ouality Act (" CEQA")
Installer agreesto coordinate its work with that of any CEQA consultant(s) retained by Site Host, to provide any reasonably available information such as current elevations and schematic drawings for use in CEQA compliance documents, and to incorporate any mitigation measuresadoptedby Site Host into the Project design.

Procurement
Installer shall procure all equipment and services required for Project design, construction, commissioning, system monitoring, warranties, operation and maintenance, as described in the Agreement and as shown in Site Host -approved final design engineering drawings, specifications and datasheets. Any proposedchangesor substitutionsmustbepresentedto SiteHostin standardsubmittal format with detailed explanations and instructions for review, comment and approval. Site Host approval of any of the submittals provided by Installer, including drawings, doesnot excuse Installer from their responsibility to meet all safety requirements, applicable codesand standardsrequirements, requirements of all Governmental Authorities and the requirements of the Agreement including this General Conditions and Technical Specifications.

Construction
Installer shall conduct all construction and construction management work for the Project, as well as schedulemanagement per the requirements of the Agreement. Any proposed changesthat represent a deviation from scope or schedulemust immediately be brought to Site Host' s attention for review. All 7 work must be performed and supervisedby skilled workers trained and experiencedin the installation of the Systems in accordance with equipment manufacturers' installation requirements. Installer shall effectively managethe scheduleand coordinate construction activities around Site Host' s maintenance activities and other construction projects where applicable.

Commissioning
Installer shall conduct all activities required for proper testing and commissioning of the Systemsand any related installations/systems. Commissioning will include testing of all systems to ensureproper operations per the design standardsand testing parameters. Installer is required to verify that: ( i) each of the Systems functions as expected within acceptableparameters and as designed at a nameplate capacity; ( ii) meets expected production output; and (iii) meets expected performance requirements described within the Agreement. Installer shall manage all necessary final inspections with all Governmental Authorities having jurisdiction over the Project, the Distribution Utility, Site Host representatives, and any other required inspectors. Installer shall also beresponsible for completing the Commissioning Schedule included as Attachment D and submitting it to Site Host for review and approval. Installer will notify Site Host no less than five ( 5) days prior to the commencement of any testing and/or inspections and Site Host and/or its representative will have the right to observe all such testsand/or inspections. As part of the commissioning activities, Installer must confirm that no negative impacts are experienced by existing facilities that connect or interface with the new installations and systems. Installer shall be solely responsible for resolving all issuesthat arise.

Distribution Utility Interconnection
Installer is responsible for coordinating and implementing all requirements related to the interconnection of the Systems with the Distribution Utility, which shall include Distribution Utility provided and installed facilities and Site facilities, at Installer' s sole cost and expense. Installer will coordinate with the Distribution Utility and Site Host to meet all milestones for the Project required by any Interconnection Agreement. Installer is responsible for compliance with all milestones, including payment milestones to the Distribution Utility for design and installation services provided by the Distribution Utility. Installer shall be responsible for obtaining written Permission to Operate for the Systemsfrom the Distribution Utility and activate the system to begin operating in compliance with the Agreement. In addition, Installer shall be responsible for all on -going terms, obligations and costs described in the Interconnection Agreement, and any other necessary permit signoffs from any Governmental Authorities having jurisdiction over the Project, to operatethe Systemsin parallel with the Distribution Utility grid.

Installer shall also be responsible for coordinating the desired rates and tariff changes with the Distribution Utility for eachof the Systems. Desired rates andtariffs for eachDistribution Utility meter are defined in the Site Assessment Table. Installer will be responsible for ensuring that each of the Systems meets the requirements for inclusion in the desired rates and tariffs and will promptly inform Site Host if there is any discrepancy between such requirements and the specifications for eachof the System set forth in the Agreement. Rate and tariff changesshall occur as soon as possible following Permission to Operate. Installer shall be responsible for ensuring that the rate and tariff change has taken place for eachDistribution Utility meter andproviding confirmation of the rate and tariff change to Site Host.

Criminal Background Check
For any and all public school Project Sites, Installer shall comply with applicable provisions of the Agreement and laws, including Education Code sections 45125.1 and 45125.2, relating. to criminal background checks for its employees.

3. ENGINEERING AND DESIGN REQUIREMENTS
Installer shall, at its own cost and expense, ( i) design, prepare and cause to be sealed all drawings and Engineering Design Packages, perform engineering studies and estimates and attend meetings as may be required (or arrange for design and engineering pursuant to a subcontract executed in accordancewith the Agreement), for the construction of the Project and interfacesrequired by the Distribution Utility including, without limitation, sizing of equipment, communication systemsand components, preparing specifications and calculationsfor equipmentand material to be included in the Project, completing the work in accordancewith the Agreement, providing administration and other servicesanditems required to complete anddeliverto SiteHostandDistributionUtility thedesignandEngineeringDesignPackages, calculations, studies, and drawings necessary to construct a fully integrated and operational Project, and (ii) provide services, attend meetings and prepare all necessarydocuments and permit applications required to obtain all Governmental Approvals, including, without limitation, coordinating with the Governmental Authorities, the Distribution Utility and other agenciesregarding Governmental Approvals necessaryfor the completion of the Project, completing the permitting process beginning from the permit application through to final approval and receipt of all applicable permits, all in accordancewith the Agreement and its exhibits, applicable law, Governmental Approvals, Site Host requirements, Distribution Utility requirements, Engineering Design Packages, industry standards, the actual condition of the Sites and all requirements to be sufficient, complete and adequate in all aspects to enable the Systems to meet all operationalrequirementsandobligationsasoutlinedin the Agreementmatchingthe warrantyperiodfor each of the Systems.

Design Codes
The Projectshall be designedandinstalledin accordancewith the relevantedition enforcedby the Governmental Authority having jurisdiction of all applicable codes, standards, and recommendations including but not limited to the following agencies:

ACI — American Concrete Institute
AISC — American Institute of Steel Construction
ANSI — American National Standards Institute.

ASCE — American Society of Civil Engineers
ASME — American Society of Mechanical Engineers
ASTM — American Society for Testing and Materials
CAL OSHA — California Occupational Safety and Health Administration CBC — California Building Code
CEC — California Electrical Code
CFC — California Fire Code
CSI — California Solar Initiative
Distribution Utility Manuals and Standards
DSA — Division of the StateArchitect for public schools ETL — Electrical Testing Laboratories
IAEI — International Association of Electrical Inspectors ICEA — Insulated Cable Engineer' s Association
IEEE — Institute of Electrical and Electronic Engineers 0 IPMVP — International Performance Measurements and Verification Protocol NEC — National Electrical Code
NEMA — National Electrical Manufacturers Association
NESC — National Electrical Safety Code
NETA — National Electrical Testing Association
NFPA — National Fire Protection Association codes, including but not limited to o NFPA 101 — Life Safety Code
o NFPA 855 — Standardfor the Installation of Stationary Energy StorageSystems UL — Underwriters Laboratories
General Requirements

3. 1. 1 Licensing
a) In all cases, engineersare to be properly licensed by the Stateof California. b) Site Host requires a minimum of a ClassB and Class C- 10 license be held by Installer and/ or their subcontractors.
c) Electrical, geotechnical, civil, structural and other engineering designsand reports are to be stampedand signed by a licensed engineer.

3. 1. 2 Solar Photovoltaic (" PV") Panel Orientation and Shading a) Solar PV panels will have a minimum shade free window between the hours of 10: OOAM and 4: OOPM ( local time) on the winter solstice. b) Orientation of the solar PV panels shall be optimized for maximum financial benefit, but in all cases with an azimuth between 180 and 270 degrees unless otherwise explicitly approved by Site Host in writing.
c) Installer shall provide a PVSyst report in PDF and excel 8760 format at every stage of the design that shows that the Solar Facility design and installation will meet the Annual Production Estimate.

3. 1. 3 Site and General System Requirements
a) Inverters and batteries shall not be placed in locations subject to exposure to direct sunlight between the hours of 10:00AM and 4:OOPM. Where inverters must be placed in locations that would be subject to direct exposure to sunlight during this window of time, they shall be provided with shade coverings or otherwise protected from continuous exposure to the sun.
b) Where applicable, the Project shall require a study, recommendations and stamp and sign off from a licensed structural engineer and a licensed geotechnical engineer. c) Sufficient access pathways and space shall be provided to and around all existing rooftop equipment to allow for ongoing maintenance of the equipment. d) All roof penetration flashing and sealing methods are to be determined, designed and implemented in accordance with the requirements of Site' s roofing Installer and/ or roofing consultant. All Site roof warranties shall be preserved. e) Where the solar PV panels are part of a ground mounted installation, Installer shall clear and grade the site substantially in accordance with the site grading plans. All vegetation inside the array boundaries shall be permanently removed. f) The low -end clearanceof ground mounted solar PV panels shall be a minimum of two feet ( 2') above grade.
g) Ground mounted solar PV panels shall include sufficient drive aisles to maintain the equipment andperform washing, including accessfor vehicles and cranesasneededto remove and replace equipment.
10 h) All roads shall be designed and installed for all weather access. i) Installer shall address all Americans with Disabilities Act (" ADA' requirements when installing Solar Facility aspart of shadestructures. Installer shall be responsible for all costs associatedwith any ADA upgradesrequired.
j) Equipment pads shall be protected by bollards. Bollards shall be permanent unless removable bollards are required to facilitate access to equipment. k) Installer shall provide erosion control, weed abatement, and security for the Site throughout construction. Installer shall remove any weeds via mechanical removal methods only.
1) Installer shall be responsible for creating and performing all requirements of a Storm Water Pollution Prevention Plan (" SWPPP"), dust control plan, pollution mitigation plan, and all other plans required by all Governmental Authorities. At a minimum, any earthwork -related or fine grading activities are to be conducted at such times that minimize construction - related fugitive dust.
m) If adequate site fencing or equivalent is not in place, equipment pads, disconnect switches and all other equipment which is atrisk for tampering shall be fenced. Fencing shall be eight feet ( 8') high with two inch ( 2") galvanized steelchain link fabric where in accordance with all local requirements. Fenced equipment pads shall have slats placed in the chain links of a color determined by the Site Host. n) Ground mounted Solar Facility arrays shall be fenced in accordancewith the NEC, NESC and requirements of any Governmental Authority and shall include provisions for at least one locking gate. If adequatesite fencing or equivalent is not in place, the fencing around ground mounted Solar Facility installations shall provide for a sixteen foot ( 16') wide clearance to allow for vehicular access and to limit shading impact on the solar PV panels.
o) Locks for all gates and electrical enclosuresto be provided by Installer but must be approved by Site Host prior to procurement. All gates shall include provision for Site Host and Installer locks to allow for accessby eachentity. p) Equipment padsshall be provided with two (2) 120VAC, 20A GFCI receptacleswhere alternative outlets are not readily available.
q) Installer will evaluate whether the Site is in a floodplain and take appropriate precautions to prevent water damage to the Project, including determining and installing the Systems including all electrical enclosuresand all other materials to be used in the Project at the appropriate height above grade to be above the 1-percent- annual- chance flood elevation.
r) Lighting requirements for Solar Facility and other Project equipment locations shall be discussed with the Site Host during design, and any lighting locations and fixture specifications shall be mutually agreedupon.
s) An arc flash study shall be performed by Installer. All required equipment labeling, fault current and coordination analysis, and recommendations for proper personal protective equipment (" PPE") shall be followed in accordance with the results of the arc flash study.
t) Geotechnical studies, where required, must include soil corrosivity and thermal resistivity testing and evaluation. All work must include consideration for the results of the testing and evaluation.

3. 1. 4 Conduit and Wiring
a) All conductors shall be in conduit. Installer shall not direct bury conductors unless explicitly approved by Site Host in writing. All conduits shall be installed according to the requirement of the NEC and all Governmental Authorities. b) Buried conduit shall be PVC and shall be covered and encasedper NEC requirements. 11 c) All below grade horizontal and vertical bends of PVC conduit shall use long radius elbows. Bending of straight PVC conduit to avoid installation of long radius elbows will not be allowed.
d) Vertical risers of buried or encased PVC conduit shall transition to the metallic conduit type specified below no higher than twelve inches ( 12") abovegradeor top of concrete.

Any exposedPVC shall be Schedule80. If transition to metallic conduit is installed as soon as or just before the conduit is no longer buried or encased, use the appropriate conduit adapter and wrap metallic conduit in 10mil corrosion protection tape where exposed to soil or concrete.
e) Where exiting from the ground, all conduits shall enter enclosuresfrom below and be madewatertight. Finish with a silicone sealing compound. f) All above ground conduit shall be electrical metallic tubing (EMT) where corrosion is not a concern, and rigid galvanized steel (RGS) where corrosion is a concern. g) All conductors 8 AWG or smaller shall be copper. Code compliant aluminum conductors may be used for conductors larger than 8 AWG. All wiring that interfaces with any of Site Host' s equipment must be copper.
h) All wiring used for grounding shall be copper.
i) Ground lugs shall be mechanical or irreversible crimp, rated for direct burial, listed to UL 467 and/ or UL 2703 and suitable for use with copper conductors. j) Unless otherwise approved by Site Host in advance, Solar Facility modules shall be grounded with hardware listed to UL 2703. Solar Facility module grounding shall be in accordancewith all requirements of the NEC and the Governmental Authority. k) All wiring shall be minimally rated to handle the voltage and current of the designed system.
1) All wiring shall be listed and labeled by a Nationally Recognized Testing Laboratory NRTL") in accordancewith Underwriters Laboratories standardsfor its purpose and location.
m) Solar PV panel string wire shall be UL listed and be appropriately rated for UV exposure where required.
n) All DC wire, other than module -to -module wire in a string that is spanning a gap less than three inches ( 3") wide shall be located in conduit. o) The Solar Facilities shall be equippedwith DC arc -fault protection in accordancewith the NEC.
p) Where there aremore than two DC strings in parallel on an MPPT, DC wiring shall be protected by overcurrent protection rated for DC circuits and marked by the manufacturer for use in solar. Fuses shall be listed and labeled by an NRTL in accordance with UL 2579.
q) All termination equipment shall be rated for the conductor type, temperature, current and voltage of the conductor being terminated.
r) Locking connectors shall mate with solar PV panel terminations and shall be certified compatible by the manufacturer of the locking connector provided with the solar PV panel.
s) All conductors used for communication will be shielded cable with a drain. t) Communicationswiring shall be in separateconduitsfrom thehigh voltageDC and AC wiring with sufficient separationto prevent interference. u) Worst -case DC voltage drop shall be limited to 2.0% unless otherwise explicitly approved by Site Host in writing. The circuit shall be defined as all wiring from the solar PV panel connectors .to the DC input terminalsat the inverter. Installer shall account for all horizontal and vertical distancesand all wire gaugetransitions. v) Worst -caseAC voltage drop for an individual inverter shall be limited to 2.0% for the Battery System and 2.5% for the Solar Facilities at maximum power, and weighted 12 averageAC voltage drop shall belimited to 2.0% at maximum power, unless otherwise explicitly approved by Site Host in writing. The circuit shall be defined as all wiring from the inverter output to the Delivery Point. Installer shall account for all horizontal and vertical distancesand all wire gaugetransitions.

3. 1. 5 Electrical Tie - In
a) The Production Meter for the Systemsshall be identified on the preliminary and final drawings and shall be located within ten ( 10') feet of the Delivery Point unless an alternative location is approved in writing by Site Host. b) Where needed, in lieu of providing and installing a Net Generation Output Meter NGOM") on eachexisting andnew Solar Facility, Installer may provide, install and program a UL 1741 CRD listed Power Control System (" PCS") that is capable of demonstrating to the Distribution Utility that the Battery Systemeither doesnot export energy to the grid or is 100% charged by the Solar Facility, thereby ensuring that the Solar Facility will receive full net energy metering (" NEM") credits from the Distribution Utility. Installer is responsible for all scope, costs and designs relating to the PCS.
c) Where needed, if Installer is unable to gain approval from the Distribution Utility for their proposed PCS as described above, A Net Generation Output Meter shall be provided for each Solar Facility in accordance with the Distribution Utility requirements. Installer is responsible for all scope, costs and designs relating to any NGOM. Installer must coordinate installation of the NGOM with existing Solar Facility owner for Sites that have a Solar Facility.
d) Where financially beneficial for the Project, the PCS shall be configured to limit net export to minimize Distribution Upgrade costs.
e) Should relocation of any circuit breakers be required to meet requirements of the Agreement, all scope, costsand designsarethe responsibility of Installer. f) If motorized circuit breakers or similar equipment is required to isolate the electrical loads from the Distribution Utility for islanded Microgrid operation, all scope, costs and designs are the responsibility of Installer.
g) If motorized circuit breakers or similar equipment is required to isolate non - critical loads from the islanded Microgrid, all scope, costs and designs are the responsibility of Installer.

3. 1. 6 Structural
a) Structural engineers shall determine all code requirements and the Project shall be designed and installed in accordance with the latest edition of all applicable codes and standards.
b) Structural engineers shall perform a structural review of the existing structures and mechanical attachment details for all equipment to be located on the roof. c) Equipment pads shall be aminimum of six inches (6") of concrete reinforced at twelve - inch ( 12") intervals with # 5 rebar unless otherwise directed by the structural engineer.

Equipment pad layouts shall include adequatespacing to accommodate maintenance activities for all equipment. A housekeepingpad elevated three inches (3") above the remaining pad surface will also be required.
d) Where electrical enclosureswill be mounted vertically to Solar Facility structural posts or other supports, two feet ( 2') minimum ground clearance and appropriate working clearances as required per NEC shall be maintained. In no case shall equipment locations create shade on any Solar Facility between the hours of 10:00AM and 4: OOPM ( solar time) on the winter solstice.
13 e) Structural engineersare to specify the gradeof steelusedin all support structures. Mill certifications showing the identification of the steel to be used on the Project and the quality thereof shall be provided to Site Host. Mill certifications shall be checked by Installer prior to accepting delivery of any steel.

Engineering Design Packages and Project Execution Plan
Installer and its subcontractors (as applicable) shall prepare and submit to Site Host for their review and approval all drawings, assessments, reports, specifications, and all other necessary documents setting forth in detail all requirements for the construction of the Project. Installer shall prepare Preliminary, 50%, 90% and 100% Engineering Design Packagesas describedherein. All engineering and installation drawings shall comply with current construction standards, codesand regulations, and adhere to all requirements of the Agreement. The system design will comply with all applicable laws and regulations. Site Host approval of any of the submittals provided by Installer, including drawings, doesnot excuseInstaller from their responsibility to meet all safety requirements, applicable codesand standards requirements, requirements of all Governmental Authorities and the requirements of the Agreement including this General Conditions and Technical Specifications.

Engineering Design Packagesshall at a minimum contain the information as outlined below for each milestone.

3. 1. 7 Preliminary and 50% Engineering_ Design Packages a) Design Drawings depicting and identifying at a minimum:
i) Solar Facility layout, where applicable
ii) Tilt and azimuth for all Solar Facility, where applicable iii) The proposed locations of all other major Solar Facility equipment including but not limited to electrical point of connection, disconnects, panelboards, inverters, meters and dataloggers, where applicable
iv) The proposed locations of all major Battery System equipment including but not limited to electrical point of connection, disconnects, transformers, panelboards, inverters, batteries, meters, controllers and dataloggers, where applicable
v) The locations of all major existing equipment, including but not limited to Distribution Utility transformer and meter, main electrical service switchgear, System electrical point of connection(s), disconnects, panelboards, inverters, arrays, meters and dataloggers. ,
b) Product data sheets and copies of manufacturers' warranties for all major pieces of equipment.
c) Completed System Site Assessment Table in native and PDF formats. d) Where applicable, PVSyst energy production modeling report in PDF format and 8760 output file in MS Excel format. The energy production model report and 8760 output files must be in the same format and use the same assumptions as those used to determine the inputs to the Agreement.
e) Where applicable, Battery Systemperformance modeling report in 4x8760 output file in MS Excel format.
f) System performance report detailing the Critical Loads and Estimated Microgrid Operation Duration, where applicable.

3. 1. 8 90% and 100% Engineering . Design Packages
a) All information required above for the Preliminary and 50% Engineering Design Packages, updated at each milestone.
14 b) A full set of Design Drawings as described in a subsequent section. c) All required drawings, assessmentsand reports stamped and signed by an engineer licensed in the appropriate discipline — structural details shall not be stamped by an electrical engineer.
d) Where applicable, full structural details of the solar PV panel mounting system, Battery System pad and anchorage, equipment support racks and anchorage, fencing design and associated calculations.
e) Microsoft Project or equivalent construction schedule (providing Gantt chart output) showing milestones, equipment order and delivery dates, and staffing requirements.

Specific milestones such as conduit installation completion, material arrival dates, interconnection date, and commissioning timeline, shall be highlighted. f) A list of those changesmade from the original proposal with the reasonstherefore.

The Engineering Design Packages will be reviewed by Site Host. Comments shall be delivered to Installer within ten ( 10) business days of submission for review. Ensuring that the Project complies with all requirements and will be installed to meet all requirements of the Agreement remains the sole responsibility of Installer.

3. 1.9 Project Execution Plan
A complete Project Execution Plan for eachSite shall be provided for review, which shall at a minimum addressthe following:
a) Material storage location
b) Lay -down and layout yard location
c) Site office location
d) Access and mobilization
e) Crane locations and traffic control
f) Method of installation
g) Human resourcesand staffing
h) Communications
i) Anticipated Project risks
The Project Execution Plan shall be reviewed and approved prior to any work being performed on the Sites. The Project Execution Plan shall be submitted as soon as reasonably possible, and no later than two ( 2) days after the 90% Engineering Design Packagedue date.

Design Drawings
A drawing summarylist shall be maintainedby the Engineerof Recordfor tracking drawingsand revisions thereof over the design and construction period, and the list shall be provided to Site Host on abi-weeklybasisor asrequested. All DesignDrawingsubmittalsshallbeaccordingto thefollowing:

3. 1. 10 Format
a) All drawings shall include a title block which at a minimum contains the Project name, Site address, Site Host logo, where applicable the DSA Identification stamp, Installer' s name, engineer's stamp, engineer's name and drawing revision table. b) Any changesin the Engineering Design Packagesfrom one Site Host submittal to the next shall be clouded.
c) Redlines shall be maintained on anot more -than -weekly basis. As -built drawings shall be completed in a reasonableamount of time following the Governmental Authority final inspection and sign off.
15 3. 1. 11 Content
The descriptions of the sheets and sheet contents below shall be considered the minimum requirement. Additional sheetsand details shall be included as neededto describe the project in adequatedetail for construction and permitting needs. a) Title Page
Information on the title pageshall include, but not be limited to the following:
i) Location of the Site
ii) Amount of land areato be occupied by the Project, expressedin squarefeet or acres as appropriate
iii) Project directory including contact information for all engineers, designersand consultants
iv) Index of drawings
v) Applicable codes and standardslist including most recent CEC/NEC vi) A scope of work narrative description
vii) System size, which shall include kWDC, kW CEC- AC and kWAC for any Solar Facility, and kWAC and kWh for any Battery System viii) Existing Solar Facility size (kWDC andkWAC), where applicable ix) Interconnection type ( NEM- PS, NEM- A, Rule 21)
x) Solar Facility module manufacturer, part number and quantities (proposedand existing where applicable), where applicable
xi) Solar Facility inverter manufacturer, part numbers and quantities ( proposed and existing where applicable), where applicable
xii) Solar Facility module mounting hardware description ( ballasted roof mount, ground mount, shadestructure mount etc.), where applicable xiii) Battery manufacturer, part numbers and quantities, where applicable xiv) Battery System inverter manufacturer, part numbers and quantities, where applicable
xv) All other information required by all Governmental Athuorities and not explicitly listed here
xvi) Benchmarking / surveycontroldataasapplicable
b) Architectural Site Plan
Information on the site plan shall include, but not be limited to the following:
i) Property lines
ii) Required setbacksand/or yards
iii) Easements
iv) Existing buildings and structures
v) Proposed locations of Major Equipment
vi) Building code analysisjustifying proposed equipment placement vii) Separation distances
viii) Fire access requirements
ix) Modifications for ADA compliance, where applicable
c) Single Line Diagrams
The single line diagrams shall accurately depict the physical electrical connections i.e., quantity, type, andsizeof conductors, quantity, size, andtypeof conduit) between all electrical equipment used in the system. Information on the single line diagrams shall include, but not be limited to the following items:
i) System size, which shall include kWDC, kW CEC- AC and kWAC for any Solar Facility, and kWAC and kWh for any Battery System 16 ii) Existing Solar Facility systemsize (kWDC and kWAC), where applicable iii) Interconnection type ( NEM- PS, NEM- A, Rule 21)
iv) Solar Facility module manufacturer, part number and quantities (proposed and existing where applicable), where applicable
v) Solar Facility inverter manufacturer, part numbers and quantities ( proposed and existing where applicable), where applicable
vi) Battery manufacturer, part numbers and quantities, where applicable vii) Battery System inverter manufacturer, part numbers and quantities, where applicable
viii) Distribution utility transformer, including size
ix) Distribution utility meter, including meter number and SAID x) Main electrical service switchgear, including bus amperage, main service disconnect amperage, voltage rating and interrupt rating xi) Solar Facility electrical point of connection, disconnects, panelboards, inverters, arrays, meters and dataloggers, where applicable xii) System interconnection tie- in scheme
xiii) All AC and DC disconnectsincluding wiring and fusing within disconnects xiv) All overcurrent protection device sizing
xv) Switchgear, including bus amperage, main over current protection device OCPD") amperage, voltage rating and interrupt rating
xvi) Transformers, including kVA, primary and secondary voltages xvii) Solar Facility modules, inverters and batteries
xviii) Number of Solar Facility modules per string
xix) Number of Solar Facility strings for eachinverter and/or combiner box xx) String labels per array or subarray
xxi) Net Generation Output Meter, Solar Production Meter, Battery System meter, Facility Load meter and any other meters, where applicable xxii) Wire type, conductor material, size and quantity usedfor eachrun xxiii) Conduit type, size and quantity of wires in eachconduit for eachrun xxiv) Total wire length for each run
xxv) Complete electrical calculations, including voltage drop, OCPD and wiring ampacity, and Solar Facility string voltage
xxvi) Monitoring data communications and power wiring
xxvii) Controls diagram including low voltage, low current andpower wiring xxviii) Security camera data communications and power wiring, where applicable xxix) Lighting, convenience outlets, and any auxiliary power circuit wiring and equipment where applicable
xxx) Make and model of all Major Equipment
d) Electrical Site Plan and Electrical Details
Information on the electrical layouts and details shall include, but not be limited to the following:
i) Plan view of locations of all electrical equipment shown on the Single Line Diagrams described above
ii) Location of the point of interconnection
iii) Enlarged views of the Battery System area, any other electrical equipment pads, and main electrical service area
iv) Elevation views of all electrical equipment
v) Locations of conduit runs
vi) Locations and sizing of spareconduits
vii) Solar Facility string map per array or subarray
17 viii) Safety label details (including, but not limited to, arc flash) e) Grounding Diagram
All electrical equipment shall be depicted, including their capacity/rating, manufacturer, part number, quantity, and reference designator where applicable.

Diagram shall indicate equipment grounding connection points and grounding conductor size. Equipment shall include but not be limited to the following:
i) - Solar Facility Modules
ii) Solar Facility Inverters
iii) Batteries
iv) Battery System Inverters
v) Transformers
vi) Switchgear
vii) AC and DC disconnects
viii) Main electrical service switchgear
ix) Meters
x) Control and Monitoring equipment
xi) Distribution panelboards
f) Structural and Civil Sheets
Information on structural and civil sheets shall include, but not be limited to the following:
i) Equipment pad(s) structural details
ii) Equipment mounting rack structural details
iii) Equipment anchorage design
iv) Fence design and structural details
v) All civil work details

4. EQUIPMENT
The System is intended to be in operation for the full warrantied period of the Major Equipment, therefore, the life cycle costs (capital expenditures and operating and maintenance expenses) for all installations and systemsmust be considered in selection criteria for all materials and equipment. Installer shall purchase and cause to be delivered to each Project Site all equipment and materials required for the Project and as described in Site Host -approved final Engineering Design Package, specifications and data sheetsand as required to construct a fully functioning Project. Any proposed changesor substitutions must be presented to Site Host in standard submittal format with detailed explanations and instructions for review, comment and approval. Minimum requirements for equipment are describedbelow. Site Host approval of any of the submittals provided by Installer, including drawings, doesnot excuseInstaller from their responsibility to meet all safety requirements, applicable codes and standards requirements, requirements of all Governmental Authorities and the requirements of the Agreement including this General Conditions and Technical Specifications.

Standards
All components shall be designed, manufactured, tested and listed in accordance with the latest applicable standardsof NEMA, ANSI, NEC, IEC andUL. Installer shall verify listing and labeling of equipmentby aNRTL prior to installation. In all casesNEC andGovernmentalAuthority rulesshall apply.
18 Factory Testing
Any equipment that is required to be factory testedto an applicable standard shall be accompanied by the results of those factory tests, and further thoseresults will be submitted to Site Host aspart of the Final Binder.

Acceptance and Care
Equipment shall be stored, handled and installed in accordance with manufacturer' s requirements.

Material received shall be identified by serial number. A report recording make, model and serial numbers of the material and equipment received shall be prepared and shall be forwarded to Site Host within ten (10) days of the material and equipment being received.

NEMA RatinL3
Enclosures mounted outdoors shall be rated a minimum of NEMA 3R. If any Site is within two ( 2) miles of any body of salt water or other potentially corrosive water, enclosuresshall be NEMA 4X in stainless steel and all other enclosures exposedto the elementsshall be NEMA 4X.

Nameplates and Labeline
All Major Equipment, panels, boxes, and associated equipment shall be clearly labeled. Reference ANSI Z535.4-2011 for guidelines describing suitable font sizes, words, colors and symbols for labels.

Nameplates and map placards shall be engraved phenolic placards made of red stock with white lettering sized appropriately for the size and purpose of the label. Installer shall submit the proposed labels for approval prior to installation. The following minimum labeling shall be installed:

A. Install engraved signs for instruction and warning identifying that the Systems are operational on the premises at appropriate locations and that there arepotentially multiple power sources on the premises — submit wording and location to Site Host for approval. In all casesNEC and Distribution Utility requirements shall dictate.

B. Install all required signage per NEC ( including arc flash requirements per NEC Article 110).

C. Install engravedphenolic placards identifying emergency disconnecting means.

D. Where applicable, provide identification of all Solar Facility DC power circuits on switches, combiner boxes and/or inverters. Clearly identify individual Solar Facility module strings within the equipment at which they terminate. Use appropriate wire color codes (i.e., red and black) for positive and negative conductors.

E. Solar Facility modules must include serial numbersin such a position asto be easily visible after installation.

Products — Approved Manufacturers and General Product Requirements Only products that meet the requirements below shall be usedin the construction of the Project, unless otherwise explicitly approved in writing by Site Host.

4. 1. 1 Approved Solar Facility Modules
Please refer to Attachment F: Major Equipment

4. 1. 2 Approved Solar Facility Module Manufacturer
19 Please refer to Attachment F: Major Equipment
Site Host' s General Guidelines for Solar Facility modules Thin- film, concentrating solar technologies, etc. technologies are not acceptedby Site Host.

All Solar Facility modules must be included on any required rebate -related approved module list as well as on the California Energy Commission' s (" CEC' l List of Eligible Photovoltaic Modules.

All Solar Facility modules shall be listed on the most recent Tier 1 Solar Panels List as determined by BloombergNEF.

All Solar Facility modules must have anti -reflective ( AR) glass surfaces.

All Solar Facility modules used on the Project shall include a minimum twenty- five ( 25) year linear power output warranty and a minimum ten ( 10) year product warranty.

All array layouts, Solar Facility module related submittals, and Solar Facility module data sheetsmust include cell andmodule efficiency ratings, and define the guaranteedproduction degradation over the warranted life of the module.

Installer will provide flash test data for all Solar Facility modules to Site Host in MS Excel format upon procurement of Solar Facility modules. Site Host, at its sole discretion, may randomly selectup to fifty ( 50) Solar Facility modules for delivery to a third -party for quality verification testing. The costsof suchverification testing shall be the responsibility of Site Host.

4. 1. 3 Approved Solar Facility Inverter Manufacturer
Please refer to Attachment F: Major Equipment
Site Host' s General Guidelines for Solar Facility Inverters Central and string inverters with a maximum input voltage of 1,000VDC are allowed where in compliance with the NEC for rooftop and shade structure mounted Solar Facility. For rooftop mounted Solar Facility, the inverter shall be certified compatible with the Approved Rapid Shutdown solution described in a subsequent section, and shall have the rapid shutdown initiation device integrated.

Central and string inverters with a maximum input voltage of 1,500VDC are allowed where in compliance with the NEC for ground mounted Solar Facility. Microinverter solutions may be proposed. All inverters must be included on any required incentive - related approved inverter list as well as on the CEC' s List of Eligible Inverters.

Inverters must meet all Distribution Utility requirements. All inverters must have a minimum 20- year warranty.

Inverter Manufacturer Preventative Maintenance and Support Services SiteHostrequirespreventativemaintenancesupportserviceswhich maybeprovided by Installer or the inverter manufacturer, as well as comprehensiveand highly responsive repair service offerings. In addition, Site Host will be monitoring the inverters' performanceremotely,.andrequirethattheinvertersutilize anopeninterface and documentedprotocols for third party monitoring software. 20 4. 1. 4 Approved Mounting Hardware — Ground Mount
Please refer to Attachment F: Major Equipment
Site Host' s General Guidelines for Solar Facility Module Mounting Hardware for Ground Mounts
Ground mounted fixed tilt Solar Facility module mounting systems shall be NRTL listed to UL 2703. Ground mounted tracking systemsshall beNRTL listed to UL 3703.

The Approved Solar Facility Modules listed above shall be on the tested and approved Solar Facility module list maintained by the mounting system manufacturer to ensure compatibility with the mounting system's integrated grounding components. Ground mounted arrays shall meet all DSA requirements.

Site Host requires that all Solar Facility module mounting solution descriptions clearly identify the mounting hardware and any engineering services related to the mounting solution. Installer shall provide full mounting solution specifications, warranty details, etc.

4. 1. 5 Approved Battery System Inverter Manufacturer
Please refer to Attachment F: Major Equipment
Site Host' s General Guidelines for Battery System Inverters All Battery System inverters must be included on any required incentive -related approved inverter list. Inverters must meet all Distribution Utility requirements. All inverters must have a minimum ten (10) year warranty.

4. 1. 6 Approved Battery Manufacturer
Please refer to Attachment F: Major Equipment
Site Host' s General Guidelines for Batteries
Lithium -ion battery chemistry is preferred. Lead acid battery chemistries are not acceptable. All batteries must have a minimum ten (10) year warranty.

Battery Manufacturer Preventative Maintenance and Support Services Site Host requires preventative maintenance support services which may be provided by Installer or the battery manufacturer, as well as comprehensiveand highly responsive repair service offerings.

4. 1. 7 Approved Data Acquisition System
Please refer to Attachment F: Major Equipment
21 4. 1. 8 Performance Monitoring and Reporting Service Installer

4. 1. 9 EPC Partner/A1soEnergyInverter Monitoring Installer EPC Partner

4.1.10 Approved Solar Facility Module Temperature Sensors AlsoEnergy

4. 1. 11 Approved Ambient Temperature Sensors
AlsoEnergy

4. 1. 12 Approved Irradiance Sensors ( Pyranometers
AlsoEnergy

4. 1. 13 Approved Wind Speed and Direction Sensors
AlsoEnergy

4. 1. 14 Approved Battery System Meter
AlsoEnergy

4. 1. 15 Approved Solar Production Meter
AlsoEnergy

4.1.16 Approved Safety Switches
Eaton

4. 1. 17 Approved Transformers
EPEC Solutions
Site Host' s General Guidelines for Transformers
Any dry -type transformers shall meet the latest Department of Energy efficiency requirements, shall have copper windings, 220°C insulation rating and 115°C maximum temperature rise rating.

Any oil -filled transformers shall be filled with a non -toxic, non-bioaccumulating, biodegradable fluid.

4. 1. 18 Approved Grounding Devices
Calpico, Eritech, Galvan, Nehring
22 5. COMMUNICATIONS AND MONITORING SYSTEMS
Installer is responsible for the complete and fully functional installation and operation of the SCADA system. Any labor, communications devices, wiring and or other materials shall be included in Installer' s cost and scope. The SCADA system shall meet all the requirements outlined in the Agreement.

Performance Monitoring & Reporting Service
Installer shall provide a Performance Monitoring and Reporting Service (" PMRS') as part of the SCADA systemto monitor and collect datafrom the Facility Load Meter, Critical Load Meter, Battery System Meter, Solar Production Meter, inverters, batteries, and all other data points applicable to the operation of the Systems. Installer shall be responsible for procuring, installing, and commissioning all SCADA equipment, and for entering into a contract with a third -party Performance Data Installer PDP'). The monitoring service requirements are as follows:

A. Installer shall provide operator and administrator level training to Site Host for using the PMRS software interface aspart of commissioning activities.

B. The PMRS software interface must allow for access via a link from Site Host' s website and must allow the users to view and download real-time and historical electricity usage, solar production, and Battery System power flow data, where applicable, at each Project Site over a variety of timescales including but not limited to a minimum of a year of fifteen 15) minute interval data. Installer shall coordinate and obtain approval of all data points to be displayed on the public webpagewith Site Host prior to implementation.

C. The PMRS software interface must allow Site Host to programmatically download via an Application Program Interface (" API') the real-time and historical electricity usage, solar production, and Battery System power flow data, where applicable, at each Project Site over a variety of timescales including a minimum of one (1) year of fifteen ( 15) minute interval data. The API must include the ability to reference most recent inverter, meter and alarm status readings.

Equipment and Components
Below is a list of the minimum equipment and componentsthat must be included aspart of the PMRS.

All equipment shall be installed to equipment manufacturer' s recommendations and best practices for the Systems.

A. Facility Load Meter( s)
Revenuegrade energy meters shall be installed to measurethe total (not net) energy usage, instantaneousdemand, power factor, etc. at eachmain switchboard where the Systems is interconnected. The load side revenuegrade energy meters shall be included aspart of the PMRS system, send data through the PDP and be displayed on the PMRS software interface.

B. Critical Load Meter( s)
For projects containing Critical Loads to be serviced by the Battery System, revenue grade energy metersshall be installed to measurethe energyusage, instantaneousdemand, power factor, etc. at each Critical Load distribution panel. The load side revenue grade energy 23 meters shall be included as part of the PMRS system, send data through the PDP and be displayed on the PMRS software interface.

C. Battery ystem Meter
For projects containing Battery Systems, revenue gradeenergy meters shall be installed to monitor power and energy flows of the Battery System at each Site. The Battery System Meter shall be located within ten feet ( 10') of the Delivery Point unless an alternative location is agreedto in writing by Site Host. The Battery System Meter shall be included as part of the PMRS system, send data through the PDP and be displayed on the PMRS software interface.

D. Solar Production Meter
For projects containing Solar Facilities, revenue grade energy meters shall be installed to monitor power and energyproduction of any Solar Facility present at each Site. The Solar Production Meter shall be located within ten feet ( 10') of the Delivery Point unless an alternative location is agreedto in writing by Site Host. The Solar Production Meter shall be included as part of the PMRS system, senddata through the PDP and be displayed on the PMRS software interface.

E. Datalogger/ Internet Gateway
F. Inverter Monitoring
If inverters arenot provided with communications aspart of the standardpackage, then the communications option shall be ordered. Where various communication package options exist, those options shall be discussedwith Site Host prior to ordering.

G. Solar Facility Array Monitoring
For projects containing SolarFacilities, if DC combiner boxesareinstalled within the array field and not integral to the Solar Facility inverters, DC monitoring shall be provided for each home run from the combiner boxes to the inverters.

H. Protective Relays, Medium Voltage Circuit Breakers and Transformers All available datapoints shall be provided through the PMRS system.

I. External Device Communication
Installer must arrange for and provide Site Host a secureand reliable internet connection adequateto allow for uploads of all datapoints from the PMRS system every fifteen ( 15) minutes at their sole cost. Installer shall provide this internet connection via a cellular modem with data service. Installer shall make this information available to Site Host through the PMRS system.

Remote Access Monitoring Portal

5. 1. 1 Power and Energy Data
Each Project Site' sPMRS web portal should display the following minimum information over a variety of timescales:
a) Battery System inverter instantaneouspower (kW)
b) Battery System stateof charge (%)
c) Battery System instantaneousenergyremaining (kWh)
24 d) Solar instantaneouspower output (kW)
e) Solar energy production ( kWh)
f) Facility entire instantaneousload without the System (kW) g) Facility instantaneousload net of Solar Facilities (kW) h) Facility instantaneousload net of Battery Systems (kW) i) Facility entire energy consumption (kWh)
0) Critical loads instantaneous load ( kW)
k) Critical loads energy consumption (kWh)
1) Billing cycle peak demandwithout the Systems (kW)
m) Billing cycle peak demandreduction due to the Battery System (kW) n) Billing cycle peak demandreduction due to the Systems (kW)

5. 1. 2 Battery System Alarms
For projects containing Battery Systems, each site should have at least the following custom alarms:
a) Whenever the billing cycle peak demand exceedsthe programmed demand threshold set at the beginning of the billing cycle.
b) The battery stateof chargeremains below a programmed value for five ( 5) consecutive days. An example is to set the value to 66% of the Battery System kWh rating in an attempt to identify if/ when the Battery System is malfunctioning. c) Any meter reports a magnitude of less than 0.1kW for one day.

5. 1. 3 Solar Facility Alarms
For projects containing Solar Facilities, each site should have at least the following custom alarms:
a) Inverter produces less than ten percent (10%) of the inverter capacity over the course of an hour between 10: 00AM and 3: OOPM. The upper limit of the alarm should be set to twice the inverter capacity.
b) Any meter reports a magnitude of less than 0.1 kW for one hour between 10:00AM and 3:OOPM. The upper limit of the alarm should be setto twice the site capacity.

5. 1. 4 Solar Facili , Analytics Pages
For projects containing Solar Facilities; eachSolar Facility PMRS should have the following tabs configured in the monitoring analytics page. They should be labeled uniformly at each site. The tabs should be labeled as follows:
a) Load Profile
i) Solar Production Meter Power ( kW)
ii) Battery System Meter Power ( kW)
iii) Facility Demand (kW)
iv) Net Consumption ( kW)
b) Inverter Output
Energy generation (kWh) per inverter. Each inverter shall have a unique identifier matching the naming convention in the as -built drawings.
c) Predicted Power
i) Solar Production Meter Power ( kW)
ii) Predicted Power ( kW)
d) Inverter vs. Solar Production Meter Power
Power output per inverter displayed with the Solar Production Meter Power 041

5. 1. 5 Settings
All System information should be filled out completely and correctly on the monitoring platform to match the as -built drawings and allow for easy identification of equipment and other System information.

6. CONSTRUCTION
Installer is required to conduct all construction and construction management work for completion of the Project. Installer shall perform all work in accordance with generally accepted industry practices, all applicable laws, regulations, codes, rules, ordinances, Government Approvals andpermitting requirements, equipment manufacturer' s requirements, and quality control inspection protocols so that the System meets or exceeds ( i) all requirements of applicable laws, Government Approvals and licenses; ( ii) equipment manufacturer' s installation specifications, and compliance with the terms and conditions of all applicable warranties and guarantees; (iii) complies with all requirements of the Interconnection Agreement; ( iv) all established safety protocols for operation and maintenance, and labeling / marking requirements; ( v) all requirements of the commissioning procedures and performance validation herein; ( vii) all requirements for any applicable federal, stateor other environmental or financial rebatesand incentives. All work must be performed and supervisedby skilled workers trained and experienced in the installation of the Systems in accordance with equipment manufacturers' installation requirements. Installer is encouraged to utilize local subcontractorsand sourcematerials andresourceslocally should they provide requisite qualifications and competitive advantages.

Site Safetv and Securi
Installer shall be solely responsible for compliance with all applicable occupational safety and health standards, rules, regulations and orders established by local agencies, the State of California, and Cal OSHA, including obtaining permits required by California Code of Regulations, Title 8, Section 341 and 341( a). In addition, Installer and all subcontractors shall comply with applicable provisions of Federal, State, and municipal safety, health, and sanitation statutes and codes. In the event there is a conflict betweentheprovisionsof theSafetyandHealthRegulationsfor Constructionpromulgatedby the U. S. Department of Labor in Title 29 CFR Part 1926, OSHA, or Cal OSHA, the more stringent provision shall prevail.

Installer will develop a site -specific OSHA approved Site Safety and Security Plan for eachProject Site and submit it for review and approval prior to the start of construction. The Site Safety and Security Plan shall include an evaluation and appropriate documentation of the safety record for all subcontractors that will be performing work on the Project, a traffic control plan, and an Injury and Illness Prevention Program plan. The Site Safety and Security Plan shall also include the location of emergency utility shutoffs and an evacuation plan. No work shall be performed on the Project prior to written confirmation that the Site Safety and Security Plan hasbeen accepted.

A safety conference shall be scheduled prior to the start of construction to review the experience modification rating, the respective safety requirements, and to discuss implementation of all health and safety provisions related to this project. Representativesfrom Installer and every subcontractor shall be present at the safety conference. Installer shall ensurethe Site Host informed of the safety conference at least five days in advanceand provided the option to attend.

Following the commencement of work on the Project, safety meetings will be held once a week with all Installer and subcontractors' employees attending. Printed names will be taken of those attending the meeting. No individual will start work at any Project Site without having attended a safety briefing on the dangersand protocols of the Project Site. Records of this training will be kept and provided for 26 review. No individual will operate a piece of equipment on which they have not had certification training. Certification shall be carried on the operator at all times.

Security of the Sitesis the sole responsibility of Installer, including any security monitoring equipment, fencing or other precautions that Installer may deem reasonably necessary. The Site Host will not be liable for theft or damage of equipment or materials stored at the Sites.

Access to and Use of Proiect Sites
The Site Host shall provide accessand areaat eachSite for the performance of the work on the Project, including lay -down area and storage area. The Site Host will grant Installer access to each Site to perform all work associatedwith theProjectandon -going operationandmaintenanceduringregular businesshours, or such other reasonablehours requestedby Installer and approved by The Site Host in accordancewith the Agreement. Accesspointsto the Sitesmustbe closelycoordinatedwith the Site Hostandapprovedin advancebeforeconstructionbegins. TheSiteHostwill issuethenecessarykeys to Installer to access Sites once all related requirements have been met. Installer shall return keys to the Site Host at any time upon request by the Site Host. Installer shall reimburse the Site Host for the cost of re -keying all of the Site Host' s locks if keys arenot returned to the Site Host.

Installeragreesnot to bring, keep, orpermitto bebroughtto, orkeptator nearanySite, anyhazardous materials, or materials which areprohibited by the Site Host or prohibited by the standard form of Site Host's insurancepolicy. Installeragreesnot to commitor sufferto be committedanywasteuponthe Sites.

Installer shall install signage at each front gate or Site entrance to identify the Project and Installer' s name and contact information upon Site Host approval of all proposed signage. Installer shall submit a prototypeof theconstructionsignsto SiteHostfor reviewandapprovalbeforepostingthesignsatthe construction sites. After approval, actual sign placement and location shall be coordinated with Site Host.

Drawings
InstallershallmaintainonecompleteEngineeringDesignPackageat eachSiteincludingonefull setof full- size plans marked to show any deviations that have beenmade from the approved plans, including but not limited to buriedor concealedconstructionfeaturesor utilities which arerevealedduringthe course of construction. Current as -built record drawings shall be accessible to Site Host at all times during the construction period. They shall be reviewed with Site Host at regular intervals. Upon completion and prior to final inspection of the Project, Installer shall submit the complete as -built EngineeringDesign Packagefor review and shall make suchrevisions or correctionsas may be necessary for them to be a true, complete, and accurate record of the Project in the opinion of Site Host.

Work - Time Constraints
Greatcareshallbetakento avoid interruptionsto theSiteHost activitiesandneighboringproperties.

Constructionactivitiesshalltakeplacebetweentypicalworkinghoursof 7:OOAMto 4:30PM, Monday through Friday, excluding recognized holidays. Reasonable efforts must be taken to minimize disturbanceto personsliving or working nearby, andto thegeneralpublic. All local ordinancesshall be adhered to regarding noise limits, otherwise a maximum of 65dB shall not be exceeded when measured at the property line. Deliveries shall take place, outside high traffic times and must be coordinatedwith SiteHost'spersonnel. Preferredhoursfor deliveriesare8:OOAMto 4:OOPM, Monday 27 through Thursday. Installer shall manage construction activities around and with consideration to the other projects occurring at the sametime where applicable. Installer will be required to provide necessaryweekly updates of scheduledactivities at each Site to Site Host.

A shutdown plan must be provided to Site Host at least two months in advance to allow for electrical shutdowns to be carefully coordinated with Site Host' s personnel. All interruptions in power shall be subject to Site Host approval and must be coordinated to take place during a time period that will minimize disruptions to Site activities. This requirement will typically mean, and Site Host reservesthe right to request, that shutdowns shall occur on weekends or after working hours. All efforts must be taken to minimize the amount of time required to complete interconnections. If required, backup power will beprovided by Installer' s generatorsduring shutdowns, at Installer' s expense. Notice of all pending shutdowns shall be provided thirty ( 30) days in advance, followed by two ( 2) weeks in advance, followed by forty- eight (48) hours in advance.

General Requirements

6. 1. 1 Conduit and Wiring
a) Locations of all junction boxes shall be reviewed with the Site Host prior to start of construction. Junction boxesshall not be installed in or nearplaygrounds andplayfields at any school sites.
b) No trenching is allowed inside playgrounds and play fields at any school sites. c) No wire splicing shall be allowed.
d) All exposedwire shall be securedevery three and a half feet (3.5') minimum. e) When terminating aluminum conductors, all terminations shall be brushed and coated with an oxide inhibitor.
f) Underground cabling shall have electrical warning tape installed approximately twelve 12") inches below finished grade in the backfill.
g) Installer shall use GPRS and potholing to survey for underground utilities andusebest practices when boring or trenching, including hand digging near buried lines.

Trenching or boring in potentially high -risk areas (gas lines) shall be coordinated with Site Host.
h) Installer shall carefully preserve all benchmarks, monuments, survey markers, and stakesand shall be solely responsible for resetting if required. i) Installer shall ensureparasitic loads (lights, security cameras, etc.) are not installed on the same circuit as the System' s Production Meter and are installed so that their load shall be included with the overall site' s Facility Load Meter measurement. j) Installer shall confirm that each of the Systems is interconnected to the correct Distribution Utility meter at each Project Site by validating the meter and service account identification numbers ( SAID) with the Distribution Utility. k) All exposedwiring shall beproperly rated for direct sun exposure. 1) Exposed wiring shall be restrainedutilizing wire clips per NEC requirements and best practices to eliminate strain on Solar Facility module junction box connections, wire pinch points and wire kinks. Strain -relief devices shall be rated and labeled for exposure to UV ( direct sunlight).
m) Conduit entry locations shall be made in manufacturer provided/ specified locations only.
n) All groundconductorsshall be protectedfrom physical damageas specifiedin the NEC.
o) Grounding wire connections must be made at closest point possible between concrete and steel, sharp edgesremoved, andpainted to match.
28 p) Power and data lines shall be located in separate conduits with appropriate separation to avoid interference.
q) All junction boxes, condolets, etc., are to be sealedwith a silicone sealing compound and made watertight.
r) H-20 rated concretehandholes with cast iron or galvanized steel lids shall be used for all underground junction box locations unless Site Host approves an alternative approach. Lids shall be bolted or welded in place with an appropriate permanent marking such as "ELEC" or " COMM" on the lid depending on the contents of the junction box.
s) Aboveground junction boxes must have tamperproof screwsand shall not be placed in areas where water ponding is anticipated.

6. 1. 2 Equipment
a) Equipment shall be stored and handled in accordance with manufacturer' s requirements.
b) Inverters and battery enclosures, where applicable, shall be placed away from all buildings where the operational noise would disturb the occupants. c) Inverters and battery enclosures, where applicable, shall not be placed in locations where fences or other barriers would obstruct replaceable air filters or prevent access for regular service and cleaning.
d) All high voltage and high amperage equipment must be installed in secure, tamper- proof, and locked enclosures to prevent unauthorized tampering for safety and theft prevention.
e) Locks for all gatesand enclosuresto be provided by Installer but must be approved by Site Host prior to procurement.
f) Where necessitatedby birds nesting underneath solar shadestructures and/or ground mounted racking systems, Installer shall be responsible for providing a means of deterring birds from nesting that is acceptableto Site Host. g) Safety labels arerequired for high voltage and high amperageequipment. h) All enclosuresshall be detailedas part of the punch list work to ensurethat any scratches, etc. areproperly coveredwith paint as appropriate. i) Solar PV panels shall have their serial numbers recorded asthey are installed, grouped and listed by DC string.
0) The Project will include installation of conduits at each Site sufficient to allow for fixture installation of security camerasat locations agreedupon with Site Host during Project design. Should Installer chooseto install camerasaspart of the overall security plan for any Site, camera selection and location shall be coordinated Site Host.

Integration of any installed safety and security systemswith the SCADA system shall be reviewed with Site Host and options provided.

6. 1. 3 Site Work
a) It is Installer' s soleresponsibility to ensurethat all work on the Project complies with all federal, state, and local code requirements, all applicable industry codes and standards, and all other requirements in the Agreement including the requirements in this General Conditions and Technical Specifications.
b) Temporary security fencing around construction areasshall be provided throughout construction, to be removed at endof construction, andpermanent fencing andbollards added as required.
c) Prior to the start of any work on Site, Installer shall take pre -construction videos and photographs of any and all areas that may be impacted as part of the Project 29 construction and shall provide the pre -construction videos and photographs to Site Host for review and reference.
d) Following the finish of construction, Installer shall take post -construction videos and photographs of all areasthat were impacted aspart of the Project construction and shall provide the post -construction videos and photographs to Site Host for review and reference.
e) Installer is solely responsible for locating and avoiding all existing underground utilities, including irrigation lines, and shall ensure the existing underground utilities and installations are not impacted by Project construction. In the event Installer damages or makes inoperable any underground or above ground utilities, it will be Installer' s full responsibility to notify Site Host immediately and make damaged/inoperable utilities whole and fully operational to Site Host' s standardsand to Site Host' s satisfaction, at Installer' s sole cost and expense. f) Installer is responsible for the repair of any damage to any Site that is caused by Installer at their sole cost and expense. Installer shall assess the condition of all areas to be used in the construction of the Systemsprior to construction and shall alert Site Host if any such area cannot accommodate wear and tear caused by ordinary construction activities. In such event, Installer shall propose a reasonableremedy or remedies to such conditions for Site Host' s consideration. g) Damage to Site Host' s facilities and/ or the Systems shall be reported to Site Host within twenty- four ( 24) hours with photographs.
h) All parking lot wheel stopsthat are damaged during construction shall be replaced at Installer' s sole expense.
i) All areaswithin the limits of construction or otherwise impacted by construction of the Project shall be restored to pre -Project conditions at Installer' s sole cost and expense including but not limited to existing rooftop equipment, fine grading, rock andconcrete spoils removal and vegetation remediation.
j) For roof mounted Solar Facilities, no metal cutting shall occur on the roof, with the exception of conduit, which shall be cut over a carpet or similar filing collector and taken off the roof in whole at the end of the Project. In no instance shall metal filings blow or otherwise endup on the surface of any Solar Facility module or the roof. k) For roof mounted Solar Facilities, the roof shall be loaded in a manner prescribed by the structural engineer so as not to overload any particular point on the roof during construction.
1) Installer will coordinate with Site Host when boring or trenching is performed, when laydown areas are determined, when major shipments are planned, or any other activities that might impact Site Host' s operations.
m) Installer shall correctly torque all such equipment or assemblies requiring torque and mark torqued bolts to designatestatusof having beentorqued. Site Host or Site Host' s representative may at any time request a test of marked bolts. Failure of a bolt designated as torqued to show that torque may require all assembliesto be re -torqued in the presenceof a third -party inspector — such inspector to be paid for by Installer. n) Installer shall maintain a clean and workmanlike construction site. Loose debris and unsafe conditions shall not be tolerated at any time.
o) Installer is responsible to obtain all necessary Site data, perform all required investigations and reasonably determine all Site data required for the design and construction of the Systems at their sole cost.
p) Installer shall be responsible for the removal and disposal of all excess soil and construction related debris generatedby Installer or subcontractorsin accordancewith applicable law.
30 q) Appropriate safety signs are required to caution drivers for speed or path restrictions near equipment pads.
r) Signage shall be provided at all drive aisle locations that coincide with a Solar Facility shadestructure clearly indicating the clearanceheight of all shadestructures. s) Safety bollards or traffic pylons with reflective strips shall be installed where any part of the Project is adjacent to a road.
t) Safety bollards or traffic pylons with reflective strips shall be installed at the corners of ground mounted Solar Facility and around all electrical equipment pads. u) Signs and barricades shall be provided and maintained by Installer and shall be in accordance with jurisdictional regulations for accident prevention and in accordance with the Site Safety and Security Plan.
v) Installer shall ensure to reasonable extent and availability of installation space that solar structures are built away from the line of sight of neighboring properties, where applicable.
w) Where applicable, installer shall identify and remove trees that would causeshading and reduce production of Solar Facility or are in direct path of construction. Installer shall mark eachtree and review with Site Host and Arborist prior to removal. Installer shall remove the tree stump, grind to twelve inches ( 12") below grade and provide a surface flush with surrounding grounds using the same material as the surrounding area.
x) Where applicable, installer shall remove light posts ( including complete concrete bollards and rebar cagesabove and below grade) and other non -building fixtures that would causeshading andreduceproduction of Solar Facility. Where light post removal is required, Installer shall mark each light post and fixture and review with Site Host prior to removal. After removal of the light post, Installer shall electrically securethe termination point at ground level in an H-20 rated concrete handhole with cast iron or galvanized steel lid. Lids shall bebolted or welded in place with a permanent marking such as " ELEC" or " LIGHTING" on the lid. Installer shall use best efforts to remove the light posts and deliver to Site Host at the Project Site in existing condition so Site Host can re - install in other areas.
y) Installer shall verify all required clearances in the field prior to construction and is solely responsible therefor.
z) Driveways in parking lots must stay open during construction. Any parking lot driveway closure must be temporary (i.e., a few hours for heavy material delivery) and shall be coordinated with Site Host.
aa) Installer is responsible for providing drinking water and sanitation facilities for all workers.
bb) Where applicable, temporary power for construction shall be arrangedand paid for by Installer.
cc) Installer must apply for fire hydrant meter permit and cover all expenses for construction water use where applicable.
dd) For water district sites, SiteHost hasthe option to supply a fire hydrant meter providing recycled water for use by Installer for construction water use where applicable.

Installer shall be responsible to provide meansof pumping, piping, transport, etc. for such water from Site Host supplied fire hydrant meter to the construction area. ee) All cut edges of galvanized strut or other support structure materials shall be cold galvanized.
ff) Saw cut concrete shall be replacedjoint to joint and match nearby area. gg) Installer shall backfill all trenches with engineered fill and compact to 95 percent minimum.
31 hh) All asphalt cuts shall be made in square or rectangular cuts to avoid inconsistent repair work. Installer shall cover asphalt trenches with hot mix asphalt, roll for compaction, and cover the width of the trench with a slurry seal after the cure period. All repairs shall be made to match existing. Any repainting of striping required to return the site to original or better conditions shall be the sole responsibility of Installer. ii) Installer shall reseedor provide sod for all areaswhere existing grasswas damaged. 6j) Installer shall conduct harmonic testing and install necessaryline filters if Site Host or the Distribution Utility detects electromagnetic interference ( EMI) following the installation of the Systems. Detection of EMI includes noticeable power interruptions in previously functional electrical equipment.

7. FINAL PROJECT CLOSEOUT
Closeout Activities
Prior to completion of work at any Site, Installer will perform the following tasks:

Complete all unfinished work described on a punch list approved by Site Host in a timely manner.

Complete final clean-up of each Site, which shall include a thorough washing of the solar PV panels for Solar Facilities. All solar PV panel washing shall be completed in accordancewith the manufacturer' s recommendations.

Confirm minimum 30-day continuous operation for the entire system, all sub -systems, and ancillary equipment without downtime following the final commissioning for projects.

Assemble and provide Site Host with the Final Binder containing all documentsoutlined below and all other required submittals.

Provide training for Site Host personnel on emergency shut -down procedures as well as standard inverter restart procedures.

Demonstrate the successful operation of the Microgrid while disconnected from the Distribution Utility grid where applicable.

Final Binder
A complete set of Project documentation in digital format, unless otherwise noted below, shall be provided to Site Host at the finish of construction for record keeping purposes (the " Final Binder').

The Project documentation shall include, at a minimum, the following documents:

Copy of executedAgreement(s) and all amendments
Copy of the Notice to Proceed to design
Copy of the Notice to Proceedto construction
Copies of all reports and studiescompleted, including but not limited to:
o Underground Utility Surveys
o Title Reports / ALTA Surveys
o Geotechnical Studies
o Environmental Studies
o Bore logs including GPS location coordinates and depth dimensions for all Project underground utilities
o Glint and Glare study
o Arc Flash / Coordination Study
Final design drawings as approved by any Governmental Authorities having jurisdiction over the Project in PDF and AutoCAD
32 Copy of all Governmental Approvals required for the Project to be constructed Copy of all Governmental Approvals required for the Project to be operational Letter to the Distribution Utility requesting final inspection in advance of Permission to Operate
Completed Commissioning Report - Attachment D
Permission to Operatenotice from the Distribution Utility All incentive related documents
All final executedDistribution Utility agreement(s) — interconnection, special facilities, etc.

As - built drawings in PDF and AutoCAD
Equipment data sheets, installation & user manuals, and warranties for all Major Equipment including but not limited to Solar Facility modules, Solar Facility module mounting systems, inverters, batteries, transformers, controllers and monitoring systems Final System Site Assessment Table in PDF and MS Excel formats Where applicable, final Battery System performance modeling report in 4x8760 output file in MS Excel format
Where applicable, final Solar Facility PVsyst modeling in PDF and 8760 MS Excel format Where applicable, final system performance report detailing the Critical Loads and Estimated Microgrid Operation Duration
Final punch list showing proof of completion of all items Letter stating Commercial Operation Date achievement and date Contact Information for all key Installer personnel including:
o Installer' s name
o Installer' s main office mailing address, phone, fax, and email o Employer Identification Number (" EIN'
o Installer' s main contact person' s name, job title, mailing address, phone number, fax number, and email
o Operations and Maintenance contact person's name, job title, mailing address, phone number, fax number, and email
Two ( 2) setsof keys to all locks, equipment, enclosures, fence gatesand boxes Operations and Maintenance manual
Site Host training completion date, including list of personnel trained in inverter shutdown and restart procedure
Monitoring system information including:
o Monitoring system hardware and internet portal specification sheets o Meter calibration records with serial numbers for all meters o Website access and operation instructions
o List of public monitoring websites
o IP addresses and login information of the data logger o Network configuration documentation
o PMRS installer contracts
Site photographs of all items listed below (electronic version only):
o Solar Facility arrays, where applicable
o Batteries, where applicable
o Inverters
o Combiner boxes
o Transformers
o Disconnects
o Panelboards/ switchgear
o Motorized circuit breakers, where applicable
33 o Electrical point of connection to existing distribution equipment o Distribution Utility meter
o Battery System Meter, Facility Load Meter, Critical Load Meter, Solar Production Meter and any other meters, where applicable
o Battery System controller, where applicable
o Microgrid controller, where applicable
o Monitoring equipment including weather sensors where applicable

8. OPERATIONS AND MAINTENANCE
Installer shall be responsible for all operations and maintenance of the Systems if included in the Agreement. The operations and maintenance shall include at a minimum:

A. All preventative maintenancerequired to maintain all equipment warranties.

B. Installer shall provide erosion control, weed abatement, and security for the Site throughout the Term at their sole expense.

C. Ground mounted arrays shall include the application at the completion of construction and as required through the Term of the Agreement of a dust control polymer additive coating within the Solar Facility areato limit solar PV panel soiling.

D. Installer shall maintain one complete Engineering Design Packagethroughout the Term of the Agreement and update with any changes made from the as -built drawings provided at the completion of construction.

E. A minimum of one annual solar PV panel washing shall be required at all sites if operations and maintenance is included in the Agreement. The timing of the washing(s) shall be coordinated with Site Host to ensure beneficial production impact.

F. Where painted steel is used for the structural components of the array, Site Host shall be provided with a hex color code and an adequateamount of touch up paint to addressminor aesthetic maintenance.
34 ATTACHMENT A - PRELIMINARY ENGINEERING DESIGN PACKAGE

TO GENERAL CONDITIONS AND TECHNICAL SPECIFICATIONS
35 1 2 3 4 5 6
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GENERAL NOTES:

PROCEDURAL NOTES:

P1. PRIOR TO COMMENCEMENT OFANY WORK, THE CONTRACTOR SHALL NOTIFY

HOLT OFANY DISCREPANCIES DISCOVERED BETWEEN THESE PLANS AND THE SITE CONDITIONS: SUCH AS DIMENSIONS, EXISTING CONDITIONS, STRUCTURE,

ELECTRICAL RUNS ( SPECIFY EXISTING ITEMS), WALLS, PARAPETS, FLASHING,

MANUFACTURER RECOMMENDATIONS OR CODES, REGULATIONS OR RULES OF AHJ.

P2 ALLDIMENSIONS OR EXISTING CONDITIONS MUST BE VERIFIED PRIOR TO COMMENCING WORK.

P3. THECONTRACTOR IS RESPONSIBLE FOR ALL BRACING AND SHORING OF EQUIPMENT DURING INSTALLATION.

P4. CONTRACTORSHALLBERESPONSIBLEFORALLSAFETYPRECAUTIONS. OSHA

REQUIREMENTS AND SAFETY MEASURES ON SITE THE ENGINEER HAS NO

OVERALL SUPERVISORYAUTHORITY AND NO DIRECT RESPONSIBILITY FOR THE SPECIFIC WORKING CONDITIONS OR FOR POSSIBLE EXISTING HAZARDS.

P5. CONTRACTOR QUESTIONS SHALL BE SUBMITTED TO HOLT PRIOR TO MAKING ANY CHANGES. HOLTWILL PROVIDE RFTS TO ENGINEER AND PH RESPONSES TO CONTRACTOR AS REQUIRED. ALL DOCUMENT CONTROL WILL BE ADMINISTERED BY HOLT.

GENERAL NDTES:

GI. ALLWORK SHALL BE PERFORMED IN A SAFE, EFFICIENT, AND WORKMAN LIKE MANNER
G2. THE ELECTRICAL CONTRACTOR IS RESPONSIBLE FOR INSTALLING ALL EQUIPMENT

AND FOLLOWING ALL MANUFACTURER' S OR ENGINEER' S DIRECTIONS AND INSTRUCTIONS SHOWN HERE.

G3. THE ELECTRICAL CONTRACTOR IS ADVISED THAT ALL DRAWINGS, COMPONENT MANUALS, ESPECIALLYTHEINVERTERMANUALS.RGIZITOBEREADUIPUNDERSTOOD PRIOR TO INSTALLATION OR ENERGIZING OF ANY EQUIPMENT. THE

CONTRACTOR IS ALSO ADVISED TO HAVE ALL COMPONENT SWITCHES IN THE OFF

OPEN) POSITION AND FUSES REMOVED PRIOR TO INSTALLATION OF FUSE -SEARING COMPONENTS.
64, INSTALLATION CREW IS TO HAVE A MINIMUM OF ONE JOURNEYMAN LEVEL

ELECTRICIAN PER THREE APPRENTICES ON SITE AT ALL TIMES WHEN ELECTRICAL WORK 15 BEING PERFORMED.

BE. CONTRACTOR SHALL HAVEA NABCEPCERTIFIED INSTALLER DIRECTLY SUPERVISE ALL PV SYSTEM INSTALLATION WORK.

GB. FOR SAFETY IT IS RECOMMENDED THE INSTALLATION CREW ALWAYS HAVE MINIMUM OF TWO PEOPLE WORKING TOGETHER.

G7. THIS SOLAR PHOTOVOLTAIC SYSTEM SHALL BE INSTALLED FOLLOWING THE CONVENTIONS OF THE DEC. ANY LOCAL CODE WHICH MAY SUPERSEDE THE CEC SHALLGOVERN.

GB. ALL COMPONENTS TO BE INSTALLED WITH THIS SYSTEM ARE TO BE USTEO BY THIRD PARTY TESTING AGENCY ( UL ETL, ETC.). EQUIPMENT SHALL BE NEMA 3R OUTDOOR RATED OR BETTER, UNLESS LOCATED INDOORS.

G9. THE ENGINEER SPECIFIES THE MINIMUM REQUIRED EQUIPMENT AND

SPECIFICATIONS TO ACCOMPLISH THE PROJECT AND THE ELECTRICAL

CONTRACTOR IS RESPONSIBLE TO ENSURE THAT THESE SPECIFICATIONS ARE

MET OR EXCEEDED WITH GOOD QUALITY EQUIPMENT, WORKMANSHIP AND SKILL G10. DC VOLTAGE FROM THE ARRAY IS ALWAYS PRESENT AT THE OC DISCONNECT

ENCLOSURE AND THE OC TERMINALS OF THE INVERTER DURING DAYUGHT HOURS. ALL PERSONS WORKING ON OR INVOLVED WITH THIS PHOTOVOLTAIC

SYSTEM MUST BE WARNED THAT SOLAR MODULES ARE ENERGIZED WHEN EXPOSED TO DAYLIGHT. THE LINE AND LOAD TERMINALS ON THE DC

DISCONNECTS MAY BE ENERGIZED IN THE OPEN POSITION AND THE SWITCH IS TO BE LABELED TO COMPLY WITH ARTICLE 690. 17 OF THE DEC.

G71. ALL PORTIONS OF THIS SOLAR ELECTRIC SYSTEM SHALL BE CLEARLY MARKED IN ACCORDANCE WITH CEC ARTICLE 690.

G12 FOR PROPER MAINTENANCE AND ISOLATION OF INVERTERS, REFER TO ISOLATION PROCEDURE IN INVERTER OPERATION MANUAL. CONTRACTOR PERFORMING THE MAINTENANCE IS RESPONSIBLE TO FOLLOW ALL LOCKOIIUTAGOUT PROCEDURES.

G13 THIS PHOTOVOLTAIC SYSTEM UTILITY INTERCONNECTION POINT SHALL MEET THE SPECIFIC REQUIREMENTS OF DEC ARTICLE 705. 12. FOLLOW THE SPECIFIC INSTRUCTIONS IN THIS DRAWING SET TO MEET THIS CODE REQUIREMENT.

G14. THEO OUNDING OF THE PHOTOVOLTAIC SYSTEM SHALL COMPLY WITH DEC 690. 45 AND DEC 690.47. IF THE REQUIREMENTS DESCRIBED IN THIS DRAWING SET

ARE CLOSELY FOLLOWED, THE GROUNDING REQUIREMENT SHALL BE MET, ANY

CHANGES SHALL BE REVIEWED AND DEEMED ACCEPTABLE BY THE ENGINEER, MANUFACTURER AND LISTING AGENCY FOR PRODUCT SAFETY.

G15. TESTINGANDCOMMISSIONINGWITHHOLT. .

G16. THE CONTRACTOR IS RESPONSIBLE FOR MOUNTING ALL EQUIPMENT PER THE ENGINEER' S REPORT OR MANUFACTURER' S SPECIFICATIONS. IF SPECIFICATIONS

ARE NOT APPARENT, THE CONTRACTOR SHALL USE DINGENT EFFORTS TO

MOUNT EQUIPMENT SUCH THAT IT WILL BE CLEAN, LEVEL AND SOLID IN ORDER TO LAST THE LIFETIME OF THIS SOLAR ELECTRIC SYSTEM.

G17. ANY METAL SHAVINGSRESULTING TRESU G FROM0 SITE WORKALL CLEANED FROM

ENCLOSURE INTERIORS TOP SURFACES OF ENCLOSURES, THE GROUND

SURFACEROOFSANDANYSHAVINGSMAYALAREASWHEREOXIDIZEDORCONDUCTIVE METAL SHAVINGS MAY CAUSE RUST, ELECTRICAL SNORT CIRCUITS - OR OTHER DAMAGE.

GIB, THE ELECTRICAL CONTRACTOR SHALL CONSI DER THE WEATHERING OF EQUIPMENT OVERTIME AND ELIMINATE 7HE POSSIBILITY OF DEGRADATION OF EQUIPMENT DUE TO WATER ENTRY AND UV EXPOSURE. AS A RESULT, HOLT

REQUIRES THE USE OF UNISTRUT OR SIMILAR MOUNTING SYSTEMS TO MOUNT ENCLOSURES, PULL BOXES. LOAD CENTERS, FUSE BOXES OR OTHER EQUIPMENT TO ROOFTOPS AND WALLS TO PREVENT WATER BUILD- UP. WEEPHOLESSHALL

NOT BE PROVIDED IN ENCLOSURES THAT WOULD CAUSE A REDUCTION IN THE ENCLOSURESNEMARATING. SEALING CONDUIT WITH A FIRERETARDANTFOAM OR

CAULKAT ENCLOSUREENTRY POINTS IS RECOMMENDEDTO MINIMIZECONDENSATION AND PESTSIN ENCLOSURES. FOR CONDUITLOCATIONSRUNNING THROUGH

WALLS FIRE RETARDANTFOAM OR CAULKMUST BE USEDTO MAINTAINTHE CURRENTFIRE RATINGOF THEWALLANDMUST COMPLYWITH UL 1479 A UL 723STANDARDS FOR THROUGH PENETRATIONS. G19. ALL
MATERALSHALLBE NEW ANDRATEDFOR UV EXPOSUREWHEREEXPOSED TO SUNLIGHT. G20.

CONSTRUCTION
STAGING OF CONCENTRATEDLOADSON ROOF SHALLBE MINIMIZED. SPECIAL

ATTENTION SHALL BE PAID TO ROOFLOADINGDURINGINSTALLATIONSUCH

THAT HEAVYITEMS ARE NOT LOADEDIN A MANNERTHATWOULD OVERLOAD THE ROOF. G21. CONTRACTOR

SHALL COORDINATE SOLAR ARRAY INSTALLATIONWORK WHERE MINIMALDAMAGE

OCCURS TO LANDSCAPECONTRACTORSHALL RESTORE ALL DAMAGED LANDSCAPE TO ORIGINAL CONDITION. G22. CONTRACTOR
SHALL RESTORE INTERIOR/EXTERIOR FINISHES TO ORIGINAL OR BETTER CONDITION.

G23. EXISTING

TREES REMOVED AS PART OF CONSTRUCTIONSHALLHAVE THEIR STUMPSGROUND T012' BELOW GRADEANDCOVEREDWITH NATIVE TOPSOILTOPSOILSHALL BE FILLED ANDCOMPACTEDTO MATCH EXISTINGGRADE. G24. PROVIOEAND

INSTALL GROUNDING TYPE BUSHING WITH GND WIRETOENCLOSUREON ALL CONCENTRICOR ECCENTRIC KNOCKOUTS. ELECTRICAL NOTES:

E1. NEVERY

PULL BOX, TERMINALBOX, AND AT ALL PLACESWHERECONDUCTORSMAY NOT

BEREADILYIDENTIFIEDBY NAMEPLATE MARKINGSON THE EQUIPMENTTO WHICH THEYCONNECT. IDENTIFYEACH CIRCUIT WITH A PLASTICLABELOR TAG FOR NUMBER, POLARITYOR PHASE. E2 THE
LAYOUT OF CONDUITSHOWNIN THESE PLANSIS INDICATIVEONLY. CONTRACTORSHALL

ROUTE AND LOCATETHE CONDUITSTO SUIT SITECONDITIONSBUT

SHALL NOT EXCEEDTHE MAXIMUMCONDUCTORLENGTHS IDENTIFIED ON THE CONDUCTORSCHEDULE. CONTRACTOR SHALL COORDINATE ALL CHANGES IN CONDUCTORANDCONDUIT WITH THE ENGINEERVIA AN RFI. E3. WHERE

CONDUCTORAND CABLE ROUTINGIS NOT SHOWN, AND DESTINATIONONLYIS INDICATED, CONTRACTORSHALL DETERMINE EXACT ROUTING AND LENGTHS REQUIRED.

A SHOP DRAWINGOF PROPOSEDINSTALLATIONSHALL BE SUPPLIEDPRIOR TO INSTALLATION. E4. BENDSSHALL

NOT DAMAGE THE RACEWAY OR SIGNIFICANTLYCHANGETHE INTERNAL DIAMETER OF RACEWAYS (NO KINKS). ES SUPPORTCONDUCTORS

IN VERTICAL CONDUITSIN ACCORDANCEWITHREQUIREMENTSIN
DEC 30D.19. EB INSTALL
ALL CONDUCTORMATERIALSINA NFATWORKMANUKEMANNER. USE GOOD TRADE PRACTICESAS REQUIRED BY CHAPTER 3 OF THEDEC. E7. INSTALL CONDUIT TO MAINTAIN PROPERCLEARANCESAND IN A NEATINCONSPICUOUSMANNER.

RUN PARALLEL AND AT RIGHTANGLESTO STRUCTURALMEMBERS
OR OTHER CONDUITS. PROVIDEBOXES, FITTINGS AND BENDS FOR CHANGESIN DIRECTION. FASTENCONDUIT SECURELYIN PLACE. E8. SUPPORT CONDUIT USI NO STEELPIPESTRAPS(OAE), LAY4N ADJUSTABLEHANGERS, CLEWS HANGERS OR SPLIT - HANGERS. HANGERSPACING SHALL BE INSTALLEDPER CEC REQUIREMENTSFOR THE TYPEOF CONDUITBEINGINSTALLED. USE APPROVED BEAMCLAMPS FOR CONNECTIONTO STRUCTURAL MEMBERS. E9.

PROVIDE

PULL, JUNCTION, OR CHRISTY BOXESWHERE REQUIREDTO FACILITATE THEINSTALLATION OF CONDUCTOR IN ADDITION TOTHOSE SHOWNON THE DRAWINGS. BENDS

IN CONDUITSBETWEENPULL BOXES SHALLNOT EXCEEDTHE EQUIVALENTOF FOUR 90 DEGREEBENDSEID. RACEWAY
N EXPA CONTRACTIONSHALLREINSTALLEDTOALLOWFOR .7( 6). THERMALEXPANSIONANDCONTRACTIONWHERENECESSARY, PERDEC 300CESMANUFACTURERINSTRUCTIONSSHALL BE FOLLOWEDANDALL ACCESSORIESSHALLBE INSTALLEDTO ENSURE PROPERFUNCTIONINGOF FITTINGS. E71. WHEN FIELD CUTTINGIS REQUIRED, THECONDUIT SHALLBE CUT SQUAREAND DEBURRED. E12.

CONDUIT

SIZES NOT SPECIFIEDSHOULDCONFORM TO CEC SPECIFICATIONS, TO INCLUDE FILL FACTOR AND DERATINGFOR NUMBER OF CONDUCTORS. E73, THE
POWER CONDUCTORSMINIMUMSIZE SHALL BE# 12 AND. E14. SAFETY REGULATIONS (LOCK OUT. TAG OUT, ETC.) IS THE FULLRESPONSIBILITYOF THE CONTRACTORDURINGCONSTRUCTION. E75. THE

CONDUCTORSIZE IS BASEDONTHE ESTIMATEDCONDUITROUTING AS SHOWN IN

THIS DRAWINGPACKAGESHOULD THE CONDUITSLENGTHINCREASE DUE TO

RELOCATIONOF SOURCE ANDIORROUTING, THE CONDUITS AND THE CONDUCTORSMAY NEED TO BE RESIZED. SUBCONTRACTORSHALL CONTACT HOLT PRIOR TO MAKINGANYFIELD CHANGES. E16. ALL
CONDUCTORSIN CONDUIT SHALLBE THWN2. XHHW-2, RHW- 2, PVWIRE, ORXLPE. USE BARE COPPERFOR GROUND FOR ALL EXTERNALGROUNDING. PVWIRE OR APPROVED EQUIVALENTSHALL BE USED FORALL EXPOSEDOR HOMERUN CONDUCTORS. E17.

FOR
INTERCONNECTIONVIA BUS TAP: A. OVERCURRENT

PROTECTION (SWITCHING DEVICE AND MEANS OF DISCONNECT)MUST BE LOCATEDPERDEC 24021. 8. THE

CONDUCTORSSHALLBE CRIMPEDWITHA CRIMPCNTERMINALLUG, MANUFACTUREDBY ILSCO, BURNDY, ONE. THE TERMINALLUG SHALL HAVEIDENTIFICATIONOR COLOR CODINGTO MATCH THECONDUCTORSIZE. TERMINAL LUGS
SHALL HAVE LONG BARRELSTO PROVIDE 2 CRIMPS PERTERMINALLUG PER CONDUCTORC. CRIMPEOTERMINAL

LUGS SHALL BE CONSTRUCTEDOF PURE COPPERAND TIN- PLATED
FORHIGH CONDUCTIVITYAND RATED FOR 600V AT 90° C WHENUSEDWITH COPPERCONDUCTORS. D, THECRI

MPMUSTBE MADE WITHTHE MANUFACTURER'S APPROVED TOOLDEVICE TO ACHIEVETHEPROPER CRIMPCONNECTION. E. USE

STAI NLESSSTEELHARDWAREWITH THE FASTENERTORQUEDTO MANUFACTURER'S

RECOMMENDATIONSONALL THREEPHASESTO COMPLY WITHARTICLE
110. 14 OF THECEC. F. MINIMUM

BEND RADIUS SHALL BE OBSERVEDTO MAINTAIN GOODCONDUCTORQUAUTY

AND CONDUCTORMANAGEMENTIN THE LOADCENTEROR

TRANSFORMERIF THIS BENDRADIUSIS TOO CONSTRICTING, USE A 90' CRIM1-ON LUG MANUFACTUREDBY ILSCO, BURNDY, ONE. 90° CRIMP -ON

LUG MUSTBE INSTALLEDWITHRATED INSULATIONTHAT MEETS OR EXCEEDS THECONDUCTORS' INSULATIONR IS BEINGUSEDWITH. IT IS RECOMMENDEDTHAT

ACCEPTABLE CLEARANCESARE MAINTAINED WITH THIS BUS
TAP FOR SAFE, CONTINUOUSOPERATION . G. FOLLOW

MANUFACTURER'S GUIDEUNES, ORTHE APPLICABLEAHJ, FOR MODIFICATIONOF BUS BAR(S). E78. ALL

CONDUITSSHALLBE FREE OF ANY OBSTRUCTIONSAND PROPERLY SECUREDBEFORE CONDUCTOR IS PULLED. E19. ELECTRICAL

CONTRACTORSHALL PROVIDE SIGNAGETO ALL ELECTRICALBOXES, JUNCTION BOXES,

PULL BOXES, OC DISCONNECTS, CONDUITRUNS, AC DISCONNECTS, SUB PANELS AND MAIN SERVICESPER CEC ARTICLE690. E20. THE

ELECTRICALCONTRACTORSHALL PERFORM INITIALHARDWARECHECKSAND CONDUCTORCONDUCTMTY CHECKS PRIOR TO TERMINATINGANYCONDUCTORS. COMPLETE

MEGGER ( INSULATION RESISTANCE) TESTING IN REFERENCETO

GROUND ANDTO EACHCONDUCTORIN THE SAMECONDUITON ALL AC
AND DC POWERCONDUCTORS. VERIFY AND DOCUMENTRESISTANCEOF AT LEAST 1DOM0ON EACH CONDUCTORUSING1009V RAMP - UP TEST FORONE MINUTE. OO NOT MEGGERTHE SOLAR MODULES. MEGGERINGIS INTENDED FORALL POWER CONDUCTORSINSTALLEDBY THE ELECTRICALCONTRACTOR. E21. ENSURE

THAT ANY EXISTINGLIGHTNINGPROTECTIONAIR TERMINALS EXTENDMINIMUM OF 10' ABOVETHETOP OF THE PV MODULES. THISCAN BE ACCOMPLISHEDBY

EXTENDING THEEXISTING AIR TERMINAL OR BY INSTALLINGNEW, TALLER AIR TERMINALWITHRATINGS EQUIVALENTTO THE EXISTINGAIR TERMINAL E22.

TORQUE:

ALL CONDUCTORSLANDINGW SCREW CONNECTIONSMUST BE PROPERLYTIGHTENED

TO THE MANUFACTURER'S TORQUE REQUIREMENTS, ALL BOLTED CONDUCTOR

TERMINATIONSMUST BE TORQUEDTO THEIR RATEDVALUE IT IS

THESUBCONTRACTOR'S RESPONSIBILITY TOENSURE ALLCONDUCTORSWITHTORQUE

REQUIREMENTSHAVE BEEN MARKEDWITH PAINT PEN OR PERMANENTMARKER AT THE TIMETHATTHE TORQUETESTWAS DONE E23. ALL
METALLICENCLOSURESSHALL BE GROUNDEDPERDEC ART. 250. E24. EQUIPMENT USED HALLBERATEDFOR THE ENYIRONRIENTIN WHICH IT IS BEINGINSTALLEDO.

E. NEMA1 3R 4 4% 12 . E25. CONTRACT

OR SHALL COMPLYWITH THE GENERALDC CONDUCTORCONDUITMAX FILL OUTLINED IN THE TABLEBELOW, A SINGLE # 6 THWW2 EGOHAS BEENINCLUDEDIN THE FILLCALCULATIONS. lDAWOPVWJITCONDUIT

FILL CONDTBILE EMT
IMC RMC PVC40 HOPE. LFMC 314' 2
3 2 2 2_ 2 5 5
5 4'- y - - 5- 10.- __ B -

9. - 1- 112° -- -
1514 - 13-- _-_ 12 12 _ 12_ 22 24
22 22 22 21 45 34
33 31 31 33 US. CONTRACTOR
SHALL NOT USE IMPACTDRIVERSON INVERTERSORWIRINGBOXES. ROOFING AND SEALING NOTES: (IF APPLICABLE) R7. A
POLYURETHANEBASEDADHESIVE SHALL BE APPLIEDTO ANY DRILLEDHOLEFOR FASTEMONG.

R2. ALL

STANDOFFS SHALLBE MADE WATERTIGHTUSING APPROVED METHODSBY THE ROOFING MATERIALMANUFACTURER, DISTRIBUTOROR ENGINEER OF RECORD, R3.

CONTRACTOR

SHALLBE RESPONSIBLE FOR PROVIDWGANYTRANSITONMATERIALWHERE DIFFERENCEOF 14' OF HEIGHTOR MORE BETWEENTHE ROOF AND
STANDOFFBASE. R4. CONTRACTOR

SHALL BE RESPONSIBLEFORINSTALLATION OF RIGID FOAMOR SPRAYFOAM

TO FILL ANYVOIDAROUNDTHE STANDOFF, FROMTHE BASE UP TO VABOVETHE ROOF. MODULEINSTALLATION
NOTES: M7. REFER
TO THE MODULEMANUALFOR DETAILS ON RIGGING. UNPACKING, HANDLING, PLANNING, AND INSTALLATION. M2. THE

MODULES MAY BE SHIPPEDWITHSEVERAL MODULESPER BOX TAKECARE WHEN OPENING THE BOX TO ENSURETHATALL MODULESARE SECURELY HANDLED. M3.

NEVER
LEAVE A MODULEUNSUPPORTEDOR UNSECURED. CONTRACTORIS RESPONSIBLE FOR ALL MATERIALHANDLINGON THE JOBSITE. GENERALSAFETY
NOTE: THE ARRAY

LAYOUTINCORPORATESDESIGN CONSIDERATIONS SET - FORTH BY THE CALIFORNIADEPARTMENT OF FORESTRY ANDFIRE PROTECTION, THE CFC AND THE IFC. THESEGUIDEUNES

INCLUDEOFFSETS AND AISLE - WAYSTO ACCOMMODATEMOVEMENTACROSS THE ROOFTOP IN THE EVENTOFAFIRE. THERE ARE ALSO CONSIDERATIONSFOR MAXIMUM DIMENSIONS OF A CONTINUOUSARRAYOR SUBARRAY. SINCEPHOTOVOLTAICPV) SOURCE

ANDOUTPUT CIRCUITSWILL BE ENERGIZEDAS LONG AS THEREIS VISIBLE LIGHT, LABELING IS SPECIFIED IN THE PLANSTO DISTINGUISHPV CONDUITS FROMEXISTING SITE CONDUIT.

BEYONDCAL - FIRE, THESEPLANSINCORPORATEOCCUPATIONALSAFETY AND HEALTH ADMINISTRATION (OSHA) GUIDELINES. THIS MAINLY PERTAINSTO MINIMUM OFFSETSFROM PARAPETS OR THE ROOFEDGE. ELECTRICALLY, THE

DESIGN SHALLMEET ALL EQUIPMENTWORKINGCLEARANCESAS DIFINED IN DEC ARTICLE110. 26 AS WELLAS CAREFULCONSIDERATIONOF EGRESS PATHSWHEN EQUIPMENT DOORS ARE OPENED. EQUIPMENTELEVATIONDRAWINGS INCORPORATETRUE - SCALED

DIMENSIONSOF TRAOESVE CONDUITBODIES AND SWEEPSTO ENSURE PROPERCONDUCTOR BEND RA0II. THIS MEASUREWILL ENSURE THAT THE CORRECTCONDUITFITTING WILL FIT THE ALLOTTEDSPACE. FURTHER, ALL EQUIPMENTSPECIFIEDSHALL BE USTEDBYANATIONALLYRECOGNIZEDTEST LAB ILL IEEE, ETC.). THE PLANS

ALSOINCORPORATEEQUIPMENTAND GROUNDING DETAILSTO ENSURE PROPERINSTALLATION

AS WELL ASACOMPLETESHEETOF THE REQUIREDLABELSAND MARKINGS, THE

LABELS ADDRESSPERTINENTARTICLES OF THE DECAS WELLAS STANDARDSADOPTED

FROM PAST PROJECTSWITH VARIOUS UTILITYCOMPANIESAND LOCAL AUTHORITIES HAVING JURISDICTION. 1301 Cp.
0 TX HvyS MISAuIh, TX
78746 E CT-.
hoIIr, able,.

FOR pEWEW

ONLYNOT FOR

CONSTRUCTIOND
3 B
A
I
Wenfl
L9.zozaVABNDTEDGENERALNOTES
n G1003
3 >, (
1202) MODULES ( 2DUMMIE5)
2) CHINT INVERTERS
1 CHIM AC COMBINERS
s= XE0. LTGROUND MOUNFl TIt n
Y,.
i -
s s
x 11800) MODULES (ODUMh9ES)

PV SOLAR SYSTEM SUMMARY
TOTALMODULECOUNT) MODULEMANF.OMODELNUMBERISTC DCRATING 3000OCELLSCREAKDUOXUGIIB 31BFG595595W PLUS 1101DUMMY MODULES
TOTAL STRINGS OF MODULES PER STRING 120 STRINGS OF 25 MODULES PV ARRAY RACKING STYLE I MANUFACTURER AND MODEL FIXED -TILT GROUND MOUNT! TERRASMART GLIDE AGILE TOTAL STC DC SYSTEM SIZE 17BS.00 kW
TOTAL INVERTER COUNT) INVERTER MANE. AND MODEL 5) CmNT CPS SCH275KLT- DOIUS- 800- 36. 250kW AC INVERTER CEC EFFICIENCY 985%( 275k"
SITE LATITUDE 38' 16' 33' N
ARRAY AZIMUTH MODULE TILT 180°/ 20° -
ABHRAE OEBIGN TEMPERATURE EXTREME MIN. 12% ml- I 3° C17fi° C IMERCONNECTIONVOLTAGE 400VAC 3qt
MORNCPD RATING 3000A TERCONNECTIONTYPE
LINE - SIDE TAP AT SOLARREADY BREAKERI ~ - +
13) CHIMINVERTERSI`
i
Sri `'f
I - - - b7: F IfICHIMAC COMBINERS OTIL
GROUNDM e ,: '
r
I r / J D3

SITEPLAN - SUMMARYSCALE
TUTS Lt
I I _
ry
a
Ys
u-
A 1R qR C
WETlANO
MITIGATION ZONE *` 1 B
to
a
l
k
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i5#
t
a
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fi• .
l
L » \ 4 A ,"
rPV EQUIPMENTAi INTERCONNECTION1)

ACUTILITYDISCONNECT- PAD

MOUNTED) A TRUE

NORTHESITE
PLAN
Al
SCALE:1164" =1'- 0° 1
2 r
k
JOINT
TRENCHCROSSINGT1 .
i'
31 }. y— UGACCONOUITRUNITYP.I HES
L BESSUNITS 6

GENERAL
SHEET NOTES HOLT 1.

ALL DIMENSIONSARE APPROXIMATEANDMUST BE FIELDVERIFIED.

2. CONDUITAND PULL BOXESSHALL BE INSTALLEDIN 1301 Cp. O TXHwyS UB315ACCORDANCE WITH THE FOLLOWINGNEC ARTICLES: 342. 26 Austin, 7X 78746FOR IMC. 34426FOR RMC, 352. 26 FORPVC, 353. 25 FORHOPE.
35826 FOR EMT CONDUIT, AND 314. 28314.30 FORwww,
NDliren4wabin— PULLBOXES.

STAMP'

3. IMPACTDRIVERSARE NOT APPROVEDFOR USE ON INVERTERS
OR WIRINGBOXES. FOR

REWEWONLY NOTFOR

CONSTRUCTIOND
G
Ju—.

OSHEETKEYNOTESOTHER
PV EONPMENTATARRAVSHALL BE 1.

INVERRACKERBANDMOUNTED. RACKMOUNTED. LL r d 2.

SWITCHGEAR, TRANSFORMER, AND BESSARE TO BE PADLL
MOUNTED.
o
w o a3.

THIS AREAHAS BEENOESIGNATEDASA WETLANDC MITIGATION
ZONE. ALL WORKFOR THE SCOPEOF THISU PROJECT
IS TOAVOIDTHIS AREAANDLEAVE IT r UNDISTURBED.

B
A6
NOTEDAxsio.vxu SITE
PLAN an
W1101.
1 1 2 3 4 5 6
gg
tom.•.•— T" w _;•.
a ,' s
plF;^ d' x a.'yY`p ;" v 3ilYAOVATIC RESOURCES AREA ° i' P I'`! M 9- J
GENERALSHEETNOTESAv HOLT

1. ALL DIMENSIONS ARE AND MUST BE FIELD
VERIFIED. J , T
y`
t 1 \ J : : ^
E
PV ARRAVA j` _ y 1

DRAINAGE WITH HVDROPHYTIC VEGETATION
J , - J lr'
f.
1202) MODULES (2DUMMIESI
r ' d25' VEGETATED BUFFER is
TO BEAVOIOED2) CH34T INVERTERS / ` "
f .
l

2. CONDUIT AND PALL BOXES SHALL BE INSTALLED IN
ACCORDANCE WITH THE FOLLOWING NEC ARTICLES: 342. 26
FOR IMC, 34426 FOR RMC, 352. 26 FOR PVC, 353. 26 FOR
HOPE. FOR EMT CONDUIT AN031d2831430 FOR
1301 Cap. O TX H" S# B315
Austin TX 76746
www. BalDelewables. mm
Ei (
f t j N{,
1) CHINTAICOMIINERS r„ .. 3 /
fFU P_ T GROUND MOU ([/
STAMP:
r
CHAIPLUNXFrNCE J,m* E
r
1650

3. IMPACT DRIVERS ARE NOT APPROVED FOR USEON
INVERTER SORWIRINGBOXES.
3' (
2 UP %1150)WIDEROW a_.
w
r
t,d " k•k- mad" ..
a. -•
Jf y.
t ( 2) UP X( 125) WIDE ROW

OR REVIEW ONLF Y
i" } '•
r
CONSTRUCTgN
P (
2) UPX1100) WIDEROW "`
Will
y$. 121UP %1751WIDEROW30' ACCESSGATE
µ
r
D
NEW CHAIN{ INK FENCE
r' ( 2)UP%(63)WIDEROW - - r' _
9 APPR0X. 171p'
Y,
D
1 JNv. m. INv6z Acc. ou

FOOT BUFFER
k . 4 $'£ '• 121UP % 1251WIDE ROW
2) UPX(50) WIDEROW1
k
s n
I
f . 1 (
2) UP X( 50) WIOE ROW . 1.
0 ' o

SHEET KEYNOTES
2 LI, 63 NfiOE ROWI ( I
LL F
r
ZE Eu d

1. INVERTERS AND OTHER PV EQUIPMENT AT ARRAY SHALL BE
RACKMOUNTED.

2. SWITCHGEAR, TRANSFORMER, AND BESS ARE TO BE PAD
O S
jKJ
30ACCESS (
j
MOUNTED.

LL
C
i'. DUMMY MODULE P OF 10
r 4 (
TY )

3. THISRESOUEARCESTRAEENDESIBETEDASPROTECTED. ALLWORTICRESOURCES TNATARE TO BE PROTECTED. ALL WORI( FOR C
U

THE SCOPE OF THIS PROJECT IS TO AVOID THIS AREAAND
2) UPX12S) WIDE ROW UGAC JI _ _ 12) UPX 17S) WIDEROW LEAVETF UNDISTURBED NO UNDERGROUND LINES ARE TO 2 , - CONDUIT RUNITYPI i' /% sM 4._
AREA
TOBEAVOIDEO AQUATIC RESOURCESAREA "' TOBEICAVOIDED
INV 04 INV.Q5 AC 02 1 €
x i '+ TOBEAV003ED f --= LNV03_ C114..' (
2) UP X( 100) WIDE ROW
BE RUN THROUGH THESE AREAS.
z
B
3 C•
9 PV SWIICHGEAR. N
22 4Z , tom
121UPX113) WIDEROW 1) AC RECOMSINER 1:- I
s , ( 1) SERVILE DISCONNECT: I k,e `
1) DA6 ENCLOSURE
v ,= -
a t G x (
PADMOUNTED' l '"_ :: } 5
ROW pB21UP %1631WIDE
121UPX150)WIDEROW + x *- b
i^y+; :°
rt'.E.' ism.'° c °'`
r 21 U._. P 36)N! EItO`W ' 4' v
i4^- ..
y
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s sr .,`' A? t, •
n"^.

UPX( 26) WIDE
71 S
J

PVARRAYB
v _.. ; S}• ?'..'` ;.

L _ TOBEAVOIDEDS(B-UM-' I(
C:
iTHINTINVERTERSTACCOMBINERSROUL(
IL10' MlllT'_
DMOUNT),' P«
aLLHYAenavaEkvA8 121UPX( 13) W DE ROW • t
p` (
3) E%ISTING CONDUITS IN JOINT TRENCH •>'
FIBER WATER BELECTRICAL Ja43'
30NA
F
MoxolFo
mu.

NORTH ...-
7' a
JOIM TRENCHCROSSINGx _.

K, r :_:"
SIARRAYAl KEPLAN-ARRAY ' '' ! . .+,
1 2 3 4 5 6
W1101z
1 2 3 4 5 6
y

GENERAL SHEET NOTES HOLT'
I
4 d
e • "
f7',
a ': Y -
K ,` \ ,,^'
p.. F' t
y ``
L '
ti•
nq _ '
T`
Sri

1. ALLIONS ARE APPROXIMATEAND MUSTBE FIELDVERIFIED.

2. CONDUITAND PULL BOXESSHALL BE INSTALLEDIN ACCORDANCE WITH THE FOLLOWINGNEC ARTICLES: 34221 1301
Cap. 0 TXHwyS N8315Austin,
TX 787d6E
1 y `
t g +. W, r• 4Y , 4
S ,
FOR
IMC, 34d1fiFOR RMC, 352. 26 FORPVC, 353. 26 FORHDPE,
35826 FOR EMTCONDUIT,MD31d. 2831d. 30 FORrrxwAaltrenewables. mm E
STAMP. iop"
l ' - 4 , - ~ '
PULLBOXES.

3. IMPACTDRIVERSARE NOT APPROVEDFOR USE ON INVERTERS
OR WIRINGBOXES. 1{: {
d' 1 FOR REVIEWONLY I sA;:.. ,; 04
r

CONSTRUCTION
s' ,^: +
ems••' PV EQUIPMENTFOR INTERCONNECTION1
1p, f ( 1)

PV TRANSFORMER,- D
i sti y S s 2'% / c ( PAD
MOUNTED) i . w
C
fi ' 1 1• J d PV EQUIPMENTFDRINTERCONNCON i& k S MAINSD INTERCONNECTIONAT •,,. n;: 9 9 . @SWITCHGEARIN ELECTRICALR00M (1)
AC SWITCHGEAR9 \
p0TIL. 1 2EOESIGNAlEO FOR SOLAR (1) PV CO`NDUITSa
t
t 13
PV
p,* EQUIPMENT FORINTERCONNECTIONI i''
1 '
S - r1 • {
t n ^ VSHES L BESSUNIT02, 200 SUNS4 (1)SOCOMEC - PADMOUNTED) p w
p
L' ^

NEWCHAIN
LINNFENCE ,"'
APPRDX, 50
W s SHEETKEYNOTESIXISTINGI2'

WATER LINELL LL
0 9_ 1. SWITCHGEAR.

TRANSFORMER. AND BESS ARE TO BE PADMOUNTED. C
PV
EQNP
ENTAT INTERCONNECTION1) AC
UTILITYDISCONNECTL' '`' PAD MOUNTED)
h yp _ 3 !.
ly}
PV
EO
IPMENTFOR INTERCONNECTION, L . I1)

SOCOMEC
SUNSYSHES L BESSUNIT012 UkWft, y V,

EXISTINGWEATHER

STATION ( PAD MOUNTED) V Q , TOBERELOCATED,
01A
I
R`;
d PGBE

UTILITY

TRANSFORMER
1 4 1+'
1 W
aAOOES
PATH,
d
t^# - I Sly -
F r.,.,,, ; a ti. •
w 1 worm A- Ls
4 i
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Hsweneuw
sxorFMo
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LL

SITEPLAN -
P01
SITEPLAN-P01 Al {
SCALE: 3132 _ -

0. 1 1 2
3 4 5 6 W1101. 3
1 2 3 4 5 6

PHOTOVOLTAIC ARRAY
3000) OCELLS OPEAK DUO% L-G115S. TBFG 595, 595W MODULES, OAR GENERAL SHEET NOTES MOLT' 120) STRINGS OF (25) MODULES
PV SWITCHGEAR ISWGR. 02)
no, J
5) CIINTCPS SCH275KTL- DOIUS30D36INVERTERS -250KWAC SELECTED RACKINOSMLLSEUL2703USTEDMANECC 800V, 1400A BUS( OAE), 1)
3/ 4- X 10'GROUNDINGR4/
0 CuBONDTO 1.

CONDUITABOVE GRACE SHALL BE EMT. ALL CONDUITBELOW 4 BARE 6 ANDEGCATTRCHEOTO RAIL ENDS WITH WEER LUGS 15OW

PVWIRE FORALL SOURCE WIRING EXOTHERMIC

BOND( TYP) NEMA
3R, 3, 0,3W,fi5 KAICO
PERCEC705.12(B)(3)(3) ELECTRODES(

TYP OFALLGROUND
RING( lYP) GROUND RODS) GRADE
SHALL BE PVCOR HDPEWITHRMC RISER. USE SCHEDULE40
FOR BELOWGRADE CONDUITRUN UNDERGRASSYAREAS.
1301 Cap. O TXHwyS 4B315BATTERY
ENERGY STORAGESYSTEM SERVICE ENTRY RATED AwlO,. TX 7B746E( 1) S000NECSUNSYS-HES-L( OCA0 5 MRNO 58LAB)[4BOVIISNJUN2O)DIWS DIGIWARE (CROPL5NEM7GROUND ROD PAD MOUNTED2. ALLCOPPERICU) CONDUCTORSIN CONDUITSHALL BE THWN-

2. XLPE. ALL EXPOSEDCONDUCTORSSHALL BE wwvi.
bal0enewables.com E
1)SOCOMIECSDNSYSHES-L( CCAB,4FWRM00SBLAB)( 4BBY ISIIJUN20] OIR $ DIG WARE [LROPCSNEMT SECTION2- SECSECTION I - SERVICEPVWIRE. ALLALUMINUMJAL) CONDUCTORSINCONDUT STAMP:
1)
750A, 3P BREAKER DISCONNECT ACD. 02 SHALL
BE XHHW-2, OR XLPE. 1)
50OA, 3P BREAKER3. ALUMINUMCONDUCTORSSHALL BE BRUSHEDAND TREATEDCHIN SCA275K1LAOIUSBC4362) 20A, 3P BREAKERSI WITH ANTIOXIDANTCOMPOUND AT TERMINALPOINTS. DCI.

SUR7EARRECOUTPUT. 1 3 1313 9 10 11 DLL-
RACKGBARRE$TDRS, 1)
20A, 2P BREAKERAFLI-
RACK MOUNTEDINV. 01 pOFMODULESIN SERIESA O
J 4.

TORQUE: ALL CONDUCTORSLANCING IN SCREWCONNECTIONS
MUST BE PROPERLYTIGHTENED TO THE1
2 - 25 Idle 25A
YP) DC= I MANUFACTURER' S TORQUEREQUIREMENTS. ALL BOLTEDFORREVIEW ONLY 1985A B 12 CONDUCTOR
TERMINATIONSMUST BE TORQUEDTO THEIR245TRINGS • '.

RATED VALUE. IT ISTHESUBCONTRACTOR'S NOT FOR PER
INVERTER '^v AC GFDI

COMM RESPONSIBILITY

TO ENSUREALL CONDUCTORSWITH TORQUE

REQUIREMENTSHAVE BEEN MARKEDWITH A PAINTCONSTRUCTION
PEN

OR PERMANENTMARKER AT THETIME THAT THE TORQUE

TEST WAS DONE TONAL
S.

SOLARENERGYPRODUCTIONMONITORING SHALL BE H)
INSTALLED AT INTERCONNECTION. D

S ROMP I
D IDENTICALTOINV.
01 B. IMPACTDRNERS ARE NOTAPPROVEDFOR USE ON INVERTERS
OR WIREBOXES. 750PJ3P
AC
COMSWERIACCDII T2 12
M.
tDOM BUS( OAE) G
1400A FUSES C
NEMA3R3W, FUSED 800A3NT. UA I F u INV.O2
191 SA DISCONNECTCEC 735.
13( B)( 3) D) I BOLTED

PRESSURE

SWITCH GFCI PER
CEC 230. 95 p 3 BACK MOUNTED
WITH MEWING WINDOWIF J d O SHEET

KEYNOTESREQUIREDBY
AHJ) I u=
o i RzO2O 1. EQUIPMENT SHALLBE INSTALLEDANDLABELED IN ACCORDANCEWITH THE CEC AND ALLAPPUCABLEI 20ARP
I D Qu o IF1V.03
19B. SA ACCOI.1801ERIACCA21BCCOMBINBDS(
QAE) 12 I
2ONJP
I

REQUIREMENTS
OF
THESERMNGUTIUTYCOMPANYANOLL ILL.
3 c a
12 D
NEMA3MR,3W,
FUSED8WAH 595.
5A

LOCALAUTHORITY
HAVINGJURISDICTION (AHJ). o Z
C
E
108SA
INY.04OISLONNECi
DEL TOS.

I21Bj(
3) I3) I 20MPI 2. DISCONNECTS
MUST COMPLYWITH CEC690. 15 ANDPROVIDEn N m RACK

MOUNTEDWARNING
SIGN PER CEC 690. 13. l7 F 198. 5A
I I 3. LISTING AGENCY
NAMESAND NUMBERSTO BE INDICATED ON a INIV. OS
12I I

POWER INVERTER AND
SOLAR MODULES PER CEC 110. 3( B). PHOTOVOLTAIC4. LABELED SYSTEMAC COMBINER' 1 SURGES.

UTILITY METER LABELED 'PHOTOVOLTAICSYSTEM ARRESTOR- GROUND ROD MONITOR.'

CT COMPARTMENT
PER EUSERC722, 330. METER DOORPER EUSERC
333. METERSOCKET IS 15J. L 1: GROUND
ROD6. LASE LED' PHOTOVOLTAICSYSTEMUTILITYDISCONNECT' K SWITCH TO BE VISUAL OPENANDACCESSIBLEAND N 3 992,
SATO
MV XFMR, SEESHEETWP601.3 CONFORM
TO CEC
705. 22. 7. LABELED 'WARNING:

THIS PANEL SUPPUEO BY MULTIPLESOURCES OF POWER:

1. UTIUTYPOWER, 2. PHOTOVOLTAICSYSTEM- DISCONNECTALL
SOURCES BEFORE SERVICING.' B MOWTORINGBOXOB.

OF INTERCONNECTION SHALL REINACCORDANCE B i01NV.01- INV.02-------------- R- j- 4- y51N1-EAPVr4D_315PRODUCTIONMEASUREMENTEMT APPRD% 70' WITHCEC 705. 11. WITHPOINTCEC705. 1TO INV.63-
INV. 05-------------- RS- 0B INI MCPyCaO_@0'- DATA O ( 6YG) 12 AWG CT CABLE (1) 1' VOLTAGESTNSWG IGHIRS-
0551N
VEMCPVC40-
60'DATA LOGGER ( 3• G)
11 GI. -2 9. PRWIDE IDENTIFICATION ALONGWITH POSITIVE& NEGATIVEPRODUCTIONMEASUREMENTBESS TO BESS. 01, CONDUCTORSPER CEC 210. 5( C)( 2). WEATHERWEATHERRSA851N1- EMTIPVC40- 60'( POWER) U) 11 AWG iHWN.7, IN 1' PVCAC-B] C' SEE SHEETWP601. 2 O N PO

STATIONPRODUCTION

MEASUREMENT
BESS TOBESSCZ 10. MIMMUMBENOING RADIUS OF PHOTOVOLTAIC MODULE TAME. ATARRAY) 24OUBOOV ( 3eG) 12AWGTHWH- 2, IN1-PVC40- 870' SEESHEETWP601.2 LEADS SHALL CONFORM WITH MINIMUMBENDING RADIUSTLELL GSM CELL _- MODEM ( t• Gp12AWG THWN2SETFORTHBY
THE MODULE MANUFACTUREROR ARTICLE 338. 24, WHICHEVER
IS MORESTRINGENT, y VIMNO11.

MATING

CONNECTORS FOR PV SOURCE CIRCUITS, PV A JUMPER CABLES, AND

MODULE LEVEL POWERELECTRONICSTO BE LISED
ANDIDENTIFIEDFOR INTERMATABIUTY, AS DESCRIBEDIN MANUFACTURER'$ INSTRUCTIONS. MATINGg a CONNECTORS THATARE
NOT LISTEDARE NOT TO BE UTILIZEDFORPROJECT.

12. AC POWER
CONDUITSTO CONVEY (3) CURRENTCARRYING A CONDUCTORSAND
AN EGC. NO NEUTRALREQUIRED. fY xo Hecewm-
ET KMA6 HOTE-D

13. ALL INVERTERS
ARE TO HAVE THE MAX250LWAC OUTPUTOPTIONSELECTED. REFER

TO INVERTER DATA SHEETON ELECTRICALSLID - SHEET
WKB01. A1

ELECTRICALSLD-PV
PV SCALE: NTS 1
2 3
4 5 6 WID601. 1
1 2 3 4

PHOTOVOLTNCARRAY
3000) OCELLS OPEAX DUO XL- GI1S. LBFG 595, 595W MODULES, DAB I 120) STRINGSOFQSIMODULES
15)CHNTCPSSLH275KTL-DO1I11DD36INVERTERS-250KWACSELECTED RACKLNG SHALL SE IJL2703 USTED AS AN EGC
BARE 6 AWG EGG ATTACHED TO RAIL ENDS WITH WEER LUGS
1500V PV WIFE FOR ALL SOURCE WIRING

BATTERY ENERGY STORAGE SYSTEM
E 1) SOCOMECSUNSYS.H- L1 CAB+5PWRMOD +5SCAB) (480V)ISIIJUN201+ MRIS OIGMIAREICROPCSNEMI 1) SOCOMECSUNSy-ES- L( 6CAB+4 PWRMOD + 5 BLAB) 1480VII511. NICUIG SEDIGIWAREICRD- KS NMISOCOMEC SUNSYS HES L BESS.01 480V,
250kW1930kWh, 250kVA
RATED, NEMA 3R PAD

MOUNTEDI
D
GROUND
ROD I
I
C
J ICIL J IllICI L J ICJL J L J L J L
J L
J L
J L
J ICJ
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J ICI
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J GROUND
ROD C

SOCOMEC
SUNSYS HES L BESS.02 4BOV,
200kW/ 93OkWh, 200kVA
RATED, NEMA 311 Al
ELECTRICALSLD - BESSSCALE:

NTS TO

SWGROI, SEE
SHEETWP601.3 TOMONITOPoNG,

L - SEE
SHEETWP601.1 I
I
I
N
241.0AS TOSWGR01, SEESHEET WPfi0f. 7 I
I
I
I
1 I
I TO
MONITORING, 1 •-
SEE SHEETWP601.1 GROUND
ROD EXOTHERMIC BOND ( TYP) 314'
X 10' GROUNDINGELECTRODES (

TYP) BATTERY
CABINET 1 L
J L J L LL- J L J LJ I l LJ L J ICIL
J L
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ICI
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J GENERAL
SHEET NOTES HOLT' mow'?
4 1.

CONOUITABOVEGRADE SHALL BE EMT. ALL CONDUITBELOW GRADE
SHALL BE PVCOR HOPEVATH RMC RISER. USE SCHEDULE
40 FORBELOWGRADE CONDUITRUN UNDERGRASSY
AREAS. 1301 Cap. 0 TXHwyS 411315ANK
TX 787462,

ALL COPPER(CUI CONDUCTORSIN CONDUITSHALL BE THWN-
20R XLPE. ALL EXPOSEDCONDUCTORSSHALL BE www.
hol!,- bI. S- E
STAMP. PVWIRE. ALLALUMINUM (AL) CONDUCTORSIN CONDUITSHALL BE XHHW-2. ORXLPE3.

ALUMINUMCONDUCTORSSHALL BE BRUSHEDAND TREATEDWITH
ANTIOXIDANTCOMPOUND AT TERMINALPOINTS. 4.

TORQUE: ALL CONDUCTORSLANDING IN SCREWCONNECTIONS

MUST BE PROPERLYTIGHTENED TO THEMANUFACTURER'
S TORQUEREQUIREMENTS. ALL BOLTEDFOR REWEWONLY CONDUCTOR

TERMINATIONSMUST BE TORQUEDTO THEIRRATED
VALUE. IT IS THESUBCONTRACTOR'S NOT FO0. RESPONSIBILITY

TO ENSUREALL CONDUCTORSWITH CONSTRUCITON TORQUE

REQUIREMENTSHAVE BEEN MARKEDWITH A PAINTPEN

OR PERMANENTMARKER AT THETIMETHAT THE TORQUETEST
WAS GONE 5.

SOIARENERGYPRODUCTICNMONITORINGSHALLSEINSTALLED
AT INTERCONNECTION. D
B.

IMPACTDRIVERSARE NOT APPROVEDFOR USE ON INVERTERS
OR WIRE BOXES. 0
0 SHEETKEYNOTESLuu-- LL
c

1. ED AND LABELEDACCORDNT

ANCECABL THE
CECANGu c OFITHREQUIREMENTSTHESE RVINGUTIUTY(AHU). YANDUTI TY COMA14 LOCAL
AUTHORITYLOCALAUTHORITYHAVING JURISDICTION (AHJI. LL
o
O
n
9 LL2
DISCONNECTSMUST COMPLYWITH CEC fi90. 15 ANDPROVIDEo WARNING SIGN PER CEC 690. 13. C U

3. USTINGAGENCY NAMES AND NUMBERSTO BE INDICATEDON POWER INVERTERAND SOLARMODULESPER CEC110.3( B). 4.

LABELED 'PHOTOVOLTAICSYSTEM ACCOMBINER- S.

UTILITYMETER LABELED'PHOTOVOLTAICSYSTEM FL MONITOR'
CT COMPARTMENTPER EUSERC31Z 330. METER1.

DOORPER EUSERC333. METERSOCKETIS 15J. i
a 6. LABELED'PNOTOVOLTAICSYSTEM UTILTY DISCONNECT' SWITCH

TO BEVISUALOPEN AND ACCESSIBLEAND N

CONFORM
TO CEC705. 22 7.

LABELEDWARNING: THIS PANELSUPPLIEDBY MULTIPLESOURCES
OF POWER: 1. UTILITYPOWER, 2. PHOTOVOLTAICSYSTEM-
DISCONNECTALL SOURCESBEFORE SERWCINWB.

POWTOFINTERCONNECTIONSHALL BE IN ACCORDANCEB WITH
CEC 705. 11. 9.

PROVIDEIDEMIFICATIONALONGWITH POSITIVEA NEGATIVECONDUCTORS PER CEC210.5¢ 1( 2). 10.

MINIMUMBENDING RADIUS OF PHOTOVOLTAICMODULE LEADS

SHALL CONFORMWITH IMMUMBENDING RADIUS A SET
FORTHBY THEMODULEMANUFACTUREROR ARTICLE33824,
WHICHEVERIS MORESTRINGENT. 11.

MATINGCONNECTORSFOR PV SOURCECIRCUITS, PV JUMPER
CABLES, AND L4000LELEVEL POWERELECTRONICSTO

BE USEDAND IDENTIFIEDFOR INTERMATABIUTY, AS DESCRIBED
IN MANUFACTURER'S INSTRUCTIONS. MATING a a CONNECTORS
THATARE NOT LISTEDARE NOT TO BE w
m a UTILIZEDFOR PROJECT. 12.

AC POWERCONDUITSTO CONVEY (3) CURRENTCARRYING CONDUCTORS AND AN EGC. NO NEUTRALREQUIRED. a.

A
Hywurern- 5 AS
NUTFD13.

ALL INVERTERSARE TO HAVETHE MAX 250kWAC OUTPUTANSIo- mm OPTION SELECTED. REFER TO INVERTERDATA SHEETONSHEET

WOOL ELECTRICAL SLD - BESS
TWP601.
2 6

PHOTOVOLTAIC ARRAY
300D) OCELLS O. PEAK DUO XLGHS. YBFG 595, 595W MODULES, OAS 1N) STRINGS OF (L5) MODULES

GENERAL SHEET NOTES

1. CONDUITABOVE GRADE SHALL BE EMT. ALL CONDUIT BELOW15) CIONT CPS SCH275KTL-0ONSa003fi INVERTERS- 2SOKWAC SELECTED RACKINGSHALLBEUL2703USTEDASANEW 01, iv GRADESRALLSEPVC ORHOPEWITHRMCRISER USE EARE6AWGEGCATTACHEOTORAIL ENDSWITHWEEBLUGS Si. R uE SCHEOULE40 FOR BELOW GRADE CONDUIT RUN UNDER 15MV PVWiREFORALLSOURCEWIRING GRASSYAREAS.

BATTERY
BAESOCOECSUNSTORAGESYSTEMREERGYSTORAGESYSTEMSPWRN00•SBCAB114801(SIIJUN20I+OIRISqGWAREICRQPCSNEMI g410 CU BOND TO
GROUNDRING (iYPJ-
1) 3M- X 1W GROUNDING

EXOTHERMIC BOND ( TYP) ELECTRODES ( TVP OF ALL

GROUND RODS)
ALL CO PER( CU. CONDUCTORSALL BE

2. ALLCOPPER(CU) CONDUCTORSCONDUUITCTORSSHALLBCONDUCTORSSHALL BE E USOCOMECSUNSYSHESL(GCAB+ 4PWR MOD+S& CAB11480VI(511JUN20I+DINS DIGIWAREICRD. PCSNEMIiY_ I' Razularn_FR 1- _ PVWIRE ALLALUMINUM (AL) CONDUCTORSIN CONDUIT ' SHALL BE XFM.2, ORXLPEI
ESSS
PVS
BESS SWRCHGEARISWGR0, 1 n„ Y ° J. ALUMINUMCONDUCTORSSHALL BE BRUSHEDAND TREATEDUS OA 1 I IiXSTjYlfDi ANTIOXIDANTCOMPOUND AT TERMINALPOINTS. GROUND ROD NEMA 3R, 30, 4W, 65 KAICO7
PERCECB 3 3)() I I' G 4. TORQUE: ALL CONDUCTORSLANDING IN SCREWENTRY SERVICEENTRY RATEDEx
SUr•la _ O CONNECTIONS

MUST BE PROPERLYTIGHTENED TO THEMANUFACTURER'
S PADMOUNTEDYGSrHE_
iCRI MZ TORQUE
REQUIREMENTS. ALL BOLTEDCONDUCTOR
TERMINATIONSMUST BE TORQUEDTO THEIRc
IC
IA
I

PVTRANSFORMER
1500kVA,
NEMA 3R, D- YG, Z=

5. 75%YJR = 7. 5 PAD

MOUNTEDTO
PVSWITCHGEAR, K 9B2.5ABOOV480V 2500A SEESHEETWP601.
01 Bry- 0NaPVXFMR.

O, 400V (

BA MCOV) LIGHTNINGARRESTOR
SECTION4-
PV

SERVICEFUSEDDISCONNECT

SECTION
3- PV
METER4B0V,2500A,30 SECTION
2- BESS

SERVICEBREAKERS

SECTION

I - MAINBREAKER
MAIN
25OGA5
211DAS 400AF 400AF BREAKER 2500AF
2500AF 430AT 3SDAT 3000AF, 30DOAT, 3P
3P 3P 3P ELECTRONIC TRIP, 65kAIC
WITH480V,

GFCI PERVIEWING
CEC
230. 95 WINDOW
IF O

REQUIREDO
BY
AHI) M
NOON

PERPG&E SPECS
Elcilnl"
as' RATED VALUE. R IS THESUBCONTRACTOR'S INTERCONNECTION RESPONSIBILITY TO ENSUREALL CONDUCTORSWITH 2
6 3000AF
I 3000A,
480VAC, 3m TORQUE

REQUIREMENTSHAVE BEEN MARKEDWITH A PAINTP
0 3000AT
DETAP

VIA PEN OR
ERMANENTMARKERATTHETIME THAT THE 2196. 9A
3000A31n4.9a jI 3P

O SOLAR
BOLARREADY70ROVETEST

WAS GONE TORQUE LSIGBREAKER
SECTION 5. SOLAR ENERGYPRODUCTIONMONITORINGSHALL BE ACD. af

PER CEC
705. 11 INSTALLEDATINTERCONNECTION. PV UTILITY
DISCONNECTa'• A
AFf D EATON PRWgEBOLTEDPRESSURESWITCH CB3034.
8- 12B- 0e0G.0AEI < V9AI fi. MAIN

BREAKER

FOR IMPACTORNERSARE
NOTAPPROVED FOR USE ON 4BOV,3000A
FUSIBLEW/] BOpA FUSES, I SERWCEOF

METERINVERTERSOR
WIRE BOXES. NEMA3R,3P,
aW, VUMM.E, LOCKABLE, 2SGDA1I
R1010078883PAD MOUNTED
WRHW 10 OF INTERCONNECTIONmmr
O F-(
Iti IINv 125L1.W P _ cEA
RA1Ds
iar l
P I
I
Fx`
snNe,
I ,-- o.
usI I
L
1654,
JA4B0VAG3PH,4W
I 4000A
BUS. 4000A MA1N(EXST1GROUNDROD
I TO i M701. OA I\ I\\\
11SEE
BHFWPW12
WP6011TOBESS. 02, N
241. 0A BUSEESHEET
WPNH.3 GROUND ROD aN•.
a, s.,
ryA4• u4 Y ww• Am rmm Wt•
J Suit' W rN141A) A00 u• W Vr, MwIWLmM VU Wb• INw FUGn•• mn4WTrp fmWA duA ww 4aM• R a' wl% 1 A 'Str; ngs, 025mo4UhA 0- t- 0NVXQ 120 15. E 10. 8 25 1447.2 275. C. PV M PVC401REE See E251GIO031 10 6 See E25/ GXXU 137 AC Aggregation Table XumWrwFmr4wN Oww4nM •
un• I VMSW
Ar•• A•
4b w• JVMeH
Ln raMNf4b
bNW votY• P' W r.. o T•
r•. ermr o. a4WaOroNeW LaNAln4 vMryp• NvAnWm•n vnue moron IAuwrAoal4u4uA O. wOSAun1 rm awlwwTm lures) n0 p7 B IHY. O 1 ACC. 01800 11% - 198. 5 250 S At XHHW- 2 3 3 500 No N A 2 I M EMT 3_ 25.0%_ OAl C_ BIV. O7 CC'. Ol 6b0 0. 99 1983 S N kNHW- 233 SOD HP_ N/ A_,__ 2 1 EMT 3 15. 0% OAi_ 0 INV03 ACG02 BW 0. 99 I98. 5 250 - S Al MIMI2 3 3 SOO Nu N/ A 2 1 EMT 3 25. 0X 0101 E RJV. 04 A0002 ._• Soo099-" 198. 5 2S6 - 5 •_•.. Ai XHHW3T 3 _--. 3 . -' S00 -, No N/ A _•_._ 2 1 _ EMT__ 3__-• 350% 0. 01. f INVASACG02 800- a" 250 l0_ l 7 SW-__-,. No EMf 3 25A9L_ OA2 G_ ACCG2 4

ACCAT -
ACRC.

Ol --'-M 0. 99 RIS8. 5 A
397. 0 500_,-
315_„----AID N NIIW- 2_
XHHW2 ^ 3YLL 3

N/ A WA
1/ 0 -^
1 i----WC40 3 31. 3% O. 6S_ H A. 1.
01 ROD 01% 595. 5- 750 SO At mIfW. 2 3 3 500 No WA 310 3 PVC40 3 32. 5% 0. 17 A[ 002000

0. 99 997. 5 1350 BUS BUS BU$ aUS BUS BUS i X ACG02
XFMR.01 E00 0. 99 991. 5 1150 670 AI XHHW- 2 3 3 - S00 No N/ A 3SO 6 PVC40 4 36. 8% 1. 15 t XFMRAISWGgA1 430 0. 99 3654. 9 2500 20 At 3 r- _ _. 3 600
Yet
600 10 PVC40 4• 34. 7% 0A5 M BIHO- 1
SWGR. O1 480 0, 93 301. 0 400 35 XHHNJ 2 AI
AHHW2 3
3 300 Y41 600 3w 1
2 NC40 3 27. 1% 0. 14 N_ BESi02SWGR.

Ol 480 0. 99 241. 0 E 350 EO Al- X/ IHW3 J 3 a--- -___--- 3?
50 Ye1
150 1 2 - P/ C40 3 136% 0. 13 P SWGROIAC0.
01 480 0. 99 2196. 9 3000 ms At 2 3 3 7M Yes 700 600 10 FVC60 5 - 24514 0. 50 p- AC0.01 WTFRCONNELTlON4B0 0. 99 2196. 9- 3000 20-_- N THWW1 3 - 3 SOp '____ Y-_._. AMC- 4_ 30. 1% 0. 07 Al ELECTRICALSLD- P01SCALE: NTSUSHEET KEYNOTES

1. EQUIPMENTSHALL

BE INSTALLED AND LABELEDIN ACCORDANCEWITH THE

CEC AND ALLAPPLICABLEREQUIREMENTSOF THE SERVING
UTIUTY COMPANYAND LOCALAUTHORITYHAVING JURISDICTION (AHJ).

2. DISCONNECTSMUST COMPLYWITH
CEC 590ASANO PROVIDEWARNING SIGN PER CEC
MAL13. C 3. USTINGAGENCY NAMES

AND NUMBERSTO BE INDICATEDON POWERINVERTERAND SOIAR
MODULESPER CEC IID. 3( B). 4. LABELED 'PHOTOVOLTAICSYSTEM AC COMBINER' S. UTILITY METERLABELEDPHOTOVOLTAIC

SYSTEMMONITOR'CT COMPARTMENT PER
EUSERC 3ZZ. 330. METERDOOR PER EUSERC333.

METER SOCKETIS 1SJ. 6. LABELEDPHOTOVOLTAICSYSTEMUTUTY

DISCONNECT' SWITCH TO BE VISUAL
OPEN ANDACCESSIBLEAND CONFORMTO CEC 705.

22. 7. LABELEDWARNING. THIS
PANELSUPPLIED BY MULTIPLESOURCESOF POWER: 1.

UTILITY POWER, 2 PHOTOVOLTAICSYSTEM -DISCONNECTALLSOURCES BEFORE SERVICING.' 8. POINTOF INTERCONNECTIONSHALL
BE IN ACCORDANCE B WITHCEC70SAI. S. PROVIDED FICATION
ALONG
WITH POSITIVE & NEGATIVE CONDUCTORSPER CEC 210.
5( C)( 2). 10. WMNUMBENDINGRADIUS

OF PHOTOVOLTAICMODULE LEADS SHALLCONFORM WITH

WMMUMBENDINGRADIUS SET FORTH BY THE
MODULEMANUFACTUREROR ARTICLE33824, WHICHEVER IS MORE
STRINGENT. 11. MATINGCONNECTORSFOR

PV SOURCE CIRCUITS, PV JUMPERCABLES, AND MODULE

LEVEL POWER ELECTRONICSTO BE USED AND
IDENTIFIEDFORINTERNATABILITY. AS DESCRIBED IN MANUFACTURERS INSTRUCTIONS.

MATING CONNECTORSTHAT ARE NOT
LISTED ARE NOT TO BE UTILIZEDFOR PROJECT. 12.

AC POWERCONDUITS
TOCONVEY (3) CURRENTCARRYINGA CONDUCTORSAND AN EGGNO NEUTRALREQUIRED. A 13. ALL INVERTERS ARE TO RAVETHE MAX 2SOSWAC OUTPUTOPTIONSELECTED. REFERTO
INVERTERDATA SKEET ON SHEErWK801. 01 C. p.
0 TXHwyS 48315Austin, TX 78746rmw.

Aduenewabhs.mm FOR

REVIEWONLY NOT

FOR CONSTRUCTIONSLD -
PDI WP601.
3 1 2 3 4 5 6
f
Al — Energy w> ,. `"- AlsnFi, ery9 tim
t-/ OL
DAS System HardwareY
Overview
Hardware Components
iaol can. o Tx R., y s 9B315
Ai¢AA, TX76746Uerewz6ks.m
STAMP:
l

NOT FOR
I + r,
x`. «_
m. va. a imxm.., a. emess
u
uj
LLLL
LL
y
s a
DATA SHEETS • MONITORING
Scale: NTS

DATASHEETS- RACKING
Scale: NTS
Q. PEAK DUO XL- G11S ® O, PEAK DUO XL- G71S SERIES
0C7G '• UCPB
SERIES ocella
ET
d - y _.
2somu skwvzoovacsrFhymYe7cersforNorth AmericaCP S
Mom, 17owls
g
s
xortfi DATASHEETS
At DATA
SHEETS - MODULEDATA SHEETS - INVERTERSScale: NTS
Scale: NTS 1 2
3 4 5 6 wKeat
IEI
ioi
ri
SUNSYS HES L" SUNSYS HEN L"
4UNSYSHESL` SUNSYS HES L°
Macular gMidocr Energy Sigroge System
hom 50 kVh / lad kYrT ro S50 kYA / l I Id kltfi eYennm
wom. v.. rm xx, ^ w. we rrre. xe. r..... mm. rn. rm. n. uau. wr nreewn. r. v,. m.,a. v.. rmnv, uu. v.. rra. m ^ u.. ac—
o
a '
3'
i
Y( f

1.A
m t III
1 a x
gsocomec zSmomec •—+- su -.-« 2socomec socomec •---- c_ a_ C1 uEllnant: els- Dt:a
Scaie: NTS
UCFs
800 Vac 3: 1 AC Combiner Solution for CPS Inverters
l
I.

Al DATASHEETS-CPSACCOMBINER
Scale: NTS
Ocps _
pHrww.^
vcPs
In - Line Cluster Mounting Bracket
Deslgned for CPS 2501275 kW Inverters & NOW, AC Combiners

DATA SHEETS - INVERTER RACKING
Scale: NTS
I OCFPs
ugI caa. o Tx Nvrys Heals
vnavanewabtAt64n,T% bi
E
aa. raa,
STAMP:

FOR REVIEW ONLY

NOT FOR

CONSTRUCTION
D
o LUW
w
laL
pig
C U
x
3 ff 101
B

DATASHEETS
WK802

ATTACHMENT B - SITE ASSESSMENT TABLE

TO GENERAL CONDITIONS AND TECHNICAL SPECIFICATIONS
36 Section 1: Site and System Information
Site Name Waterman Treatment Plant
Site Designator A
Service Account ID 7605929944
Meter Number 1010078883
Service Address 0
Site Address 2900 Vista Grande Circle, Fairfield, CA 95434 Solar Facility Target " Annual Production Estimate"( kWh) 3110442 Target Battery System Size( kW) 450 ( 200 kW + 250 kW)
Target Battery System Size( kWh) 1860

Battery System Round Trip Efficiency
Additional System De - rate (%) 2. 010%
Anticipated Annual Full Discharges ( Yr. 1 #) 329i
Battery System Transformer Size ( kVA) 20ahl2. 50
Capable of Exporting for NEM Credits( Y/ N) N!//h
Battery System WarrantyTerm( YRS) 1& 00)
Section 4: EVCS
of Future L1 EV Chargers Planned NUA1
of Future L2 EV Chargers Planned N%IA
of Conduits Needed for Future Installation of L1 EV
ChargerIt
N/lAl
of Conduits Needed for Future Installation of L2 EV Charger' Section 5: System Offer Costs
Total " De eiop n Co in i Pr < E ) 385, 000. 00
00- pa0,46 ,, a Uip d Cos c ucied l ' ContractS'um'(f$j d S` a lest i S U C i i"
1 $,
SiteEle.c rcaSyserxv[1 grados tslrlcludedrn Gonta t1y t d ©lst - tP$ 4„ 00QO PowerPr'
c IncentiveAmount($)
I- N, IkA, IncentiveProgram
N!// A\ ITCPercentage(%)
W/ 16) SolarFacility
Cost($) i Rund, Ued] iinl PPABatterySystemCost ($)
I B; undfie-, d] iniPPjA PPATem
Y ) 2. 5 Solar Faci,li
Pow -, , ice' - 4 IT S e7nax' i 01..121: D Soir ac''
i ' P WNMPRRMs a o (° o) 0. 0% B tery S em
eruieesR 4e' o ) i M/) A, 0. 0% S s.
e ' I ' :,, ,
U. l. e ( 1
S stem' errm i t Y 4;:721, 702
Increase to Solar Facility " Power Price" due to XXX($/ k 01:0005 . remental Cost for Solar Facility Extended Inverter Warranty ff Incremental Cost to use all Copper Wiring($) N/ A,
Incremental Cost to add Backup Power Solution($)
Incremental Cost to add XXXXX($) NM
Section 6: Utility Billing ( assume 0% escalation for rates) YR 0 Existing Utility Bill
YR 0 Existing Utility Bill Demand Charges($) 423-, 265`; YR 0 Existing Utility Bill Energy Charges($) 6:04; 90i7 YR i Total Utility Bill($) Please, reference Saui:ngs_ Analysis Repor ; Utility Bill Energy Charges Post -Solar PV ($) Please; refe.re'nceSavfjng ., Analy5 isR'ep'ort; Utility Bill Demand Charges Post -Solar PV($) Please; reference! Sa,Wbos,A , alysi'& R:ep.ort.

Utility Bill Energy Charges Post -Battery System ($) Pl'ease ref'erence Savi',ng-sjAnal'y i5 Report:

Utility Bill Demand Charges Post -Battery System($) Pease referencel Sauings' Analysis Repo'rt i Plea`sejreferen' ce S'avi'ngs,Arralys,t's;Report;
P1'eased;refereecejS_b ) njgs3AnaAGysils,R'epo;rf?
Pleaserefere, nce)S1ai'ngs,Analsysiis;Regorrte
Section 7: Other Cost Savings ( assume 0% escalation for rates) Demand Response Revenue ( YR 1$) j Please: refe.ren:ce Saui'ngs;An'alysi's Repo.rit? Other
Section 8: Performance Guarantee
So . Fa11OM , UpWIGKa R
r nRate(YR` 1$IkVuh)
ola F i'lity 0 tp Ge A a E t lo) 0. 0%
olar F I t rjO t i aka' e R t A'nnua Escal`at,orv
0 S'a a` ty © ui Giaran ee( iYR1rUNhj 0
53'/cycl'e
BAffeerj - v , te' R'ate(INSETIINITS)
tter S m GRLAIMEMMIUM / on 0. 0%
B'atlGer C a . 1teR%aGeA nut" Ea anon(%i) t.. 0. 0%
B bte y S m c a C le '( R 1 ) 2961
M; at ter i Cut arnt'eed(Ccles(YR#) 4 i 29,6j
Battery Sy t ' G a a C cle t C = e °°) Se:e; S;ocomec Spec Sheetfor'd'egrced'afiuycu! rve, Ba tety e i Ccr; ee 'CycleannualChange(,I',_6,) See Soc.o:m:ec,$ pe:c She;et f' d'egredati' onftrue. teySsemC u e'( R h 1674
I b. S sfe iiGuat ot($) J

ATTACHMENT C - PROJECT SCHEDULE

TO GENERAL CONDITIONS AND TECHNICAL SPECIFICATIONS
37 ATTACHMENT D - COMMISSIONING SCHEDULE

TO GENERAL CONDITIONS AND TECHNICAL SPECIFICATIONS
IID
T '
T sk ! Task Name
l.. _...

FO M_de_. -
1 I
ql City ofFai
T _,__
Duration Stan iFinish ( Predecessors . Successors Fab1124 , Feb 18, 24 Geb2S 2d Mar3' 2A . Mar10,' 24 Mt17 ' 2a JMar24,' 24 i — M.. T_ LW . T .. F.„_$-. 5..,,M_. L ,.wLL_ J... S 51.M ..7 . w l T_I. f_.. 5 ..5- M.LT . W:..T.:_F $ $.. I. M.L7-i W T_•_. 5_ 5 M _ T_LW. I T! F_'. S. t. 5 i M T 2 1 Award Date 0days Wed 4124124 Wed 4/ 24/ 24 32
3 Q Engineering Notice to Proceed 0 days Fri 8/ 23124 Fri 8/ 23/ 24 34 4 4 50% Design Drawings due to Site Host 0 days Mon 30/ 7/ 24 Mon 10/ 7/ 24 39, 47, 57, 38 1 5 R 50% Drawings Site Host Review 0 days Mon 10/ 14/ 24 Mon 10/ 14/ 24 40, 48, 58 I 6 4 90%- Design Drawings due to Site Host 0 days Thu 31/ 7/ 24 Thu 11/ 7/ 24 41, 49, 59 7 4 90% Drawings Site Host Review _ 0 days Thu 11/ 14/ 24 Thu 11/ 14/ 24 42, 50 iB
g 100% Design Drawings due to Site Host 0 days Thu 11/ 28/ 24 Thu 11/ 28/ 24 43, 51 9 4 10D% drawings Site Host Review 0 days Thu 12/ 5/ 24- Thu 12/ 5/ 24 44, 52 10 R IFCStamped Drawings 0days Mon 12/ 16/ 24 Mon 12/ 16/ 24 45, 53 i 11 S Design & Engineering Completed 0 days Mon 12/ 16/ 24 12/ 16/ 24 36 12 On Interconnection Sign- offwith the Utility 0 days
Mon
Mon 5/ 5/ 25 Mon 5/ 5/ 25 62
1t3 1 Permits AHl Approval Completed 0days Mon S/ 5/ 25 Mon 5/ 5/ 25 61 14 4 Major Equipment Order Date 0 days Tue 9/ 17/ 24 Tue 9/ 17/ 24 6755 is '' tl Procurement Completed 0 days Fri 10/ 3/ 25 Fri 10/ 3/ 25 67 j t6 j 4 Site Preparatilon Start 0 days Fri 8/ 22/ 25 Fri 8/ 22/ 25 80SS I 17 I r%
Site Preparatilon Completed 0 days Tue 9/ 16/ 25 Tue 9/ 16/ 25_ 1 18 t'. Construction Start 0 days
80 lid 8/ 22/ 25 Fri 8/ 22/ 25 79SS
19 Mechanical Installation Completed - 0 days Tue 10/ 7/ 25 Tue 10/ 7/ 25 84 j 20 k Electrical Installation Completed 0 days Mon 2/ 2/ 26 Man 2/ 2/ 26 90 21 ` 4 Interconnection Sign off 0 days Mon 1/ 19/ 26 Mon 1/ 19/ 26 109 22 N PV Completion 0 days Tue 2/ 3/ 26 Tue 2/ 3/ 26 110 23 Utility Meter and Rate Switch Submittal 0 days Thu 12/ 5/ 19 Thu 12/ 5/ 19 24 + S Permission to Operate ( PTO) 0 days Wed 4/ 29/ 26 Wed 4/ 29/ 26 117 A 25 S Testing & Commissioning Completed 0 days Wed 5/ 13/ 26 Wed 5/ 13/ 26 118 26 I S Commercial Operation 0 days Mon 6/ 15/ 26_ Mon 6/ 15/ 26 122 27 Date _ _
Commercial Operation Deadline 0 days Thu 12/ 5/ 19 Thu 12/ 5/ 19 28 14 Final Completion 0days Tue7/ 7/ 26 Tue 7/ 7/ 26 130 j 29
3Di
I
4 04 Contract
31 n Proposal Submission
Contract Execution
33 j 1t Gty uncd Protect Approva
j 34 Q 4 Engineering Notice to7Fra eed.
35 Pre - Construction
36 1 4 Design & Engineering
i 37 T. Electrical Design
38 R Due Diligence Analysis
4 39
4 50% Design Drawings due to Site Host
40 4 50% Drawings Site Host Review
41 4 90% Design Drawings due to Site Host
l 90% Drawings Site Host Review
43 4 100% Design Drawings due to Site Host
44 a 100% drawings Site Host Review
j 45i IFC Stamped Drawings
1 46 R Structural Design
j 47 r6 Due Diligence Analysis
48 S 50% Design Drawings due to Site Host
49 1 44 50% Drawings Site Host Review
i5DI
90- A Design Drawings
51 4 90% Drawings Site Host Review
j 52 100% Design Drawings due to Site Host
53 I 4 100% drawings Site Host Review
54 I IFC Stamped Drawings
206 days Wed 11/ 8/ 23 Fri 8/ 23/ 24
1 day Wed 11/ 8/ 23 Wed 11/ 8/ 23 32
105 days Thu 11/ 30/ 23 Wed 4/ 24/ 24 31 2
286 days Mon 8/ 26/ 24 Fri 10/ 3/ 25
80 days Mon 8/ 26/ 24 Mon 22/ 16/ 24 - 11
80 days Mon 8/ 26/ 24 Mon 22/ 16/ 24 66
15 days Mon 8/ 26/ 24 Mon 9/ 16/ 24 34 4, 39, 73
15 days Tue 9/ 17/ 24 Mon 30/ 7/ 24 38 40, 4
5 days Tue 10/ 8/ 24 Mon 10/ 14/ 24 39 41, 5, 60
18 days Tue 10/ 15/ 24 Thu 11/ 7/ 24 40 42, 6
5 days Fri 1118/ 24 Thu 11/ 14/ 24 41 43, 7
10 days Fri 11/ 15/ 24 Thu 11/ 28/ 24 42 44, 8
5 days Fri 21/ 29/ 24 Thu 12/ 5/ 24 43 45, 9, 71
7 days Fri 12/ 6/ 24 Mon 12/ 16/ 24 44 10, 62, 77
75 days Mon 8/ 26/ 24 Mon 12/ 9/ 24 65
15 days Mon 8/ 26/ 24 Mon 9/ 16/ 24 34SS 48, 4
15 days Tue 9/ 27/ 24 Mon 10/ 7/ 24 47 49, 5
5 days Tue 10/ 8/ 24 Mon 10/ 14/ 24 48 5016
15 days Tue 10/ 15/ 24 Mon 11/ 4/ 24 49 51, 7
5 days Tue 11/ 5/ 24 Mon 11/ 11/ 24 50 52, 8
10days Tue 12/ 12/ 24 Mon 11/ 25/ 24 51 5319
5 days Tue 11/ 26/ 24 Mon 1212/ 24 52 54, 10
5 days Tue 12/ 3/ 24 Mon 1219/ 24 53
Task summary Inactive Mdenane Duration - only start -only E 6lemal Mil- oneO Manual Progress — Dat:

Project: Project Schedule
Date: Tue 7/ 30/ 24
spit ............................. Plujttbummary t-'—'—' 1 udaie summary r'-'---"' t Manual 5umnwry Ratlup Finish - only 7 txamine a Milestone • Inactive Task Mama] Task ttil Manual Summary Winnal Tasks - Progress

Page 1 ends

Fairfield City CouncilSeptember 16, 2025

Fairfield City Council
September 16, 2025