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2310 N Spurgeon St - Plan
Bldg #101125194 & Elect #20187009 CITY OF SANTA ANA Planning and Building Agency w z J ry w a- 4'-116�� ry D- I N NW W_"14 I SW 1 S NE I ►E SE 150'-23" Nl� PROPERTY LINE K (E) - Single Family Dwelling 25'-74" O (E)200A SERVIC I (N)-ADU . • d Q v 4 Roof Access, no Q• Q doors or window underneath Q PROPOSED PV SYSTEM ON EXISTING ROOF OF HOUSE PROPERTY LINE d v A a DRIVEWAY Q Q v 4 June 6, 2025 www. Loyd W Martin .com Solar Structures Engineering #2025-1416 Structural Only "NO VENTS (DORMER, PLUMBING,MECHANICAL) TO BE COVERED OR ROUTED AROUND SOLAR MODULES" ALL EQUIPMENT SHALL BE PAINTED PRIOR TO INSPECTION SOLAR AREA:315.34FT2 HOUSE ROOF AREA:816FT2 (315.34/816)X100=38.64% ROOF COVERAGE I� IVUDSSUANJCE Class: C46 WNPITE ,4,T�92878 C Dat01) 707-6537 i SAPP PHOTOVOLTAIC SOLAR SYSTEM 23 10 N 5FURGEON 5T SANTA ANA, CA, 9 270G � ISSUE DATE: 6/1 /2025 REV.: DATE:=DESCRIPTION: BY `I I P'AIT CH EL5EA AND CARTER SAPP APN#0030G I 1 1 23 10 N 5PU RGEON 5T SANTA AN A, CA, 3 270G TEL(7G0)-473-G2G5 -DRAWN BY: CHK.: APV.: MR MR MR :STAMP: K&v-i.� La f " KEVI N LAFEERTY CONTRACTOR C4G EET SITE PLAN :SHEET NUMBER: SHEET NUMBER CITY OF SANTA ANA Planning and Building Agency I MAX NOTE: CONNECTION SUPPORTS NOT TO SPAN FURTHER THAN 6' (72") MAX. WITH MIN 2.5" PENETRATION INTO R.R.s June 6, 2025 www. Loyd W Martin .com Solar Structures Engineering #2025-1416 Structural Only 3/ n 4 n v'I/ n c-+ C- (NOTE: Engineer of Record assumes that all structural components of the existing building were permitted and met the requirements of the Building Code at the time of construction. Solar Contractor shall field verify that the roof framing is in its existing permitted condition and capable of supporting required live loads. Framing specified on solar plans shall be assumed to be minimum size and spacing, actual framing may be different. Class: C46 WNPITE ,4,T�92878 C Dat01) 707-6537 SAPP PHOTOVOLTAIC SOLAR SYSTEM 23 10 N 5PURGEON 5T 5ANTA ANA,CA,9270G � ISSUE DATE: 6/1 /2025 REV.: DATE:=DESCRIPTION: BY:-7 (`1 IP'AIT CH EL5EA AND CARTER 5APP APN#0030G I 1 1 23 10 N 5PURGEON 5T 5ANTA ANA,CA,9270G TEL(7G0)-473-G2G5 -DRAWN BY: CHK.: APV.: MR MR MR :STAMP: K&v-i.� La f " KEVI N LAFEERTY CONTRACTOR C4G EET CONNECTION DETAIL :SHEET NUMBER: SHEET NUMBER CITY OF SANTA ANA Planning and Building Agency I IMPORTANT: 36 INCH CLEARANCE FOR ELECTRICAL EQUIPMENT PROVIDED *Location of Installation of NEW equipment will be a MIN of 36" away from the Gas Meter **Cables in discontigious groups of panels to be placed in 3/4" EMT Point Load NOT to exceed 401bs (15) LONGI LR5-54HABB 400M PV MODULES & (15) 108PLUS-72-2-US Microlnverters, INSTALLED ON EXISTING ROOF USE2 TO THWN-2 CONDUCTORS (NOTE: EXACT LOCATION TO VARY) 271-1011 R�NjQ�c UN ON ROOF AND )ES NOT ENTER HOUSING ENVELOPE (NOTE: EXACT LOCATION TO VARY.) `15 1-L1`I11 ulUL 1V 1L 11`4 Ll\ 1 111`I LL June 6, 2025 www. Loyd W Martin .corn Solar Structures Engineering #2025-1416 Structural Only ENPHASE MICROINVERTERS FULLY MEET RAPID SHUTDOWN REQUIREMENTS IN THE NEW CODE WITHOUT THE NEED TO INSTALL ANY ADDITIONAL ELECTRICAL EQUIPMENT NW W-99" SW N S NE Now-E SE Class: C46 WPITE N,4,T�92878 C Dat01) 707-6537 SAPP PHOTOVOLTAIC SOLAR SYSTEM 23 10 N 5FURGEON 5T 5ANTA ANA,CA,9270G � ISSUE DATE: 6/1 /2025 REV.: DATE:=DESCRIPTION: BY:-7 (`1 IP'AIT CH EL5EA AND CARTER 5APP APN#0030G I I 23 10 N 5PURGEON 5T 5ANTA ANA,CA,9270G TEL(7G0)-473-G2G5 -DRAWN BY: CHK.: APV.: MR MR R,::] :STAMP: K&v-i.� La f " KEVI N LAFEERTY CONTRACTOR C4G EET ELECTRICAL PLOT PLAN :SHEET NUMBER: SHEET NUMBER CITY OF SANTA ANA Planning and Building Agency I DC:6.000kW AC:5.538W (NOT CENTER FED) (3) #10 AWG TH"-2 Copper and (1) #8 TH"-2 Copper xwH (N)-ENPHASE COMBINER PANEL GEC in 3/4" EMT 000 �ft5A IOKAIC Tag Tag@ (2) Enphase AC Interconnect Cables & # 10 AWG THWN-2 Copper & O PRE T . `.GR FOR MONIott)RWG KEIf N GND 2 A (4) (1) #6 AWG Bare Copper EGC (free four (1) #8 THWN-2 Copper GEC in 3/4" EMT O NOT physical damage) in free air (Continuos) trenched portion in 1 "SCH80 PVC IN USE EXISTING BUILDING GROUNDING ELECTRODE UFFER (N) 25A O o 0 O __0) U O L,_� 15A (N) -30A AC Disconnect EXISTING Visible Blade Lockable in Open 200A Service Panel 200A Buss Barr Position Rated 30A with NOT CENTER FED Outdoor SQUARE-D Proposed: 25PV breaker in SERVICE Backfed Breaker to be secured @ opposite (load) end of bus from Main Breaker "New Copper ground rod or irreversibly crimped to building's GEC" 15A 18.15A 18.15A* 1.25=22.68A J-Box so 25A PV Breaker o.k String 1 consists of (8) LONGI LR5-54HABB 400M PV Modules connected to (8) IQ8PLUS-72-2-US Microlnverters (97.6% CEC) The Microlnverters' AC Outputs are connected in Parallel@ 240V Split Phase, (13) Maximum units per branch String 2 consists of (7) LONGI LR5-54HABB 400M PV Modules connected to (7) IQ8PLUS-72-2-US Microlnverters (97.6% CEC) The Microlnverters' AC Outputs are connected in Parallel@ 240V Split Phase' (13) Maximum units per branch If existing ufer not found, req'd sis" diameter ground rod 8'0" min embedment and req'd 6'-0" apart between 2 groundings" Wire Sizing Calculations PV MODULE SPECS: String 1: Junction Box to Combiner: 9.68A Max Current X 1.25 (NEC 690.8(B)(1)) / .76 ambient tempt correction ( 125°F)=15.92A so IOAWG MICRO -INVERTER SPECS: THWN-2 w/ Cond. Amp Rating of 40A o.k MODULE MANUFACTURER: LONGI INVERTER MANUFACTURER: ENPHASE String 2: Junction Box to Combiner : 8.47A Max Current X 1.25 (NEC 690.8(B)(1)) / .76 ambient tempt correction ( 125°F)=13.93A so IOAWG MODULE MODEL# LR5-54HABB 400M MODULE MODEL # IQ8PLUS-72-2-US THWN-2 w/ Cond. Amp Rating of 40A o.k MAX POWER -POINT CURRENT (Imp): 12.93A MAX INPUT VOLTAGE: 60V Combiner Panel to Service : 18.15A Max Current X 1.25 (Continuous Current) / .91 ambient temp correction( 95°F)=24.93A so IOAWG MAX POWER -POINT VOLTAGE (Vmp): 30.94V THWN-2 w/ Cond. Ampt Rating of 40A o.k OPEN -CIRCUIT VOLTAGE (Voc): 37.05V PEAK OUTPUT POWER(AC): 300W Ungrounded System: SHORT-CIRCUIT CURRENT (Isc): 13.72A NOMINAL AC VOLTAGE: 240V THE DC CIRCUIT MEETS THE REQUIREMENTS. FOR ENPHASE MICROINVERTERS FULLY MEET RAPID MAXIMUM POWER (Pmax): 40OW NOMINAL OUTPUT CURRECT: 1.21A UNGROUNDED PV ARRAYS IN NEC 690.35. SHUTDOWN REQUIREMENTS IN THE NEW CODE CEC PTC RATING: 378.30W MAX UNITS PER 20A BRANCH: 13 EQUIPMENT GROUND IS PROVIDED IN THE ENGAGE WITHOUT THE NEED TO INSTALL ANY ADDITIONAL CABLE. NO ADDITIONAL GEC OR GROUND IS ELECTRICAL EQUIPMENT CEC WEIGHTED EFFICIENCY: 97.6% REQUIRED. GROUND FAULT PRETECTION (GFP) IS INTEGRATED INTO THE MICRO INVERTER ARC FAULT PROTECTION FOR ENPHASE: — pis requirement s for direct currsnl i DCi Arc -Fault Cirourt protecuon and only applaes to systems w-th �C voltages aoove 80 VDC. Enphase % icroinverter systems are exempted from this requirement as they *Location of Installation of NEW equipment will be a MIN of 3 6" always operate wee oe ow 80 Vbn -i+e requrement is basically unchanged from the NEC 2011, and it is .;nnecessar, to ado DC AFCt to an Enphase lAcroirnverter System inslatlebon away from the Gas Meter Code Reference "Cables in discontigious groups of panels to be placed in 3/4" EMT 990.11 Arc -Fault Circuit Protection (Direct Current). Photovoltaic sys_-ems with do source crwits cc ouip.,t cjrcu2s or oath. operating at a PV system maximum system voltage of 8(} volts ALL PV SYSTEM COMPONENTS SHALL BE PROTECTED FROM PHYSICAL DAMAGE or greater. Brie,' be protected try a rsted {tic) arc-fsult crc:urt interrupter PV type or other sys* n compoonents ;-steo to provide equilalera Vateccon. Metal enclosures that are not physically continuous from equipment to the grounding electrode shall be made electrically continuous by bonding each end of the raceway or enclosure to the grounding electrode conductor ..��,IL ifs �li� • 1�' Class: C46 UITE ����A�,192878 C DAtp51) 707-6537 SAPP PHOTOVOLTAIC SOLAR SYSTEM 23 10 N 5FURGEON 5T 5ANTA ANA, CA, 9 270G ISSUE DATE: 6/1 /2025 REV.: DATE:=DESCRIPTION: BY-.---' 7 ChELSEA AND CARTER 5AFF AFN#0030G I I I 23 10 N 5FURGEON 5T SANTA ANA, CA, 9 270G TEL(7GO)-473-G2G5 -DRAWN BY: CHK.: APV.: MR MR MR STAMP: Kevi,w La f'ferhq KEVI N LA1=I=ERTY CONTRACTOR C4G EET SINGLE LINE :SHEET NUMBER: SHEET NUMBER E2 CMS CITY OF SANTA ANA Planning and Building Agency � Markings Informational note: ANSI ZS35.4 provides guidelines for the design of safety signs and labels for application to products. A phenolic plaque with contrasting colors between the text and background would meet the intent of the code for permanency. No type size is specified, but 20 point (3/8") should be considered the minimum. WARN LNG L` VERTER Ot TPl T CONNECTION DO NOT RELOCATE THIS 0%' ERC I * RRENT DEN7CE CEC705.12 (DH7) Optional AC Disconnect per AHJ - — PV RV PV PV ■ DC l� AL 23 10 N 5PURGEON 5T 5ANTA ANA,CA,9270G SOLAR PANELS 1(91 } AC %r ARN LNG DUAL POWER SOt � RCES SECOND SOt'RUE IS PHOTOVOL'i' aIC S%'srE11*1 RATED AC OUTPUT Ct -RRE` r 18.15 ANIPS AC NOR1►iAL OPERAT LNG VOLTAG E 240 VOLTS CEC 690.54 & (' L( 705.12(U I(4 ) Pti' SVSTE.y1 AC Di SCONNI ECT SECOND SOURCE 1S PHOTOVOLTAK SYSTEN1 RATED ACO TPt'T CtIRRE'VT 18.15 .MN,AMN, AC NORMAL OPERAT LNG VOLTAG E 240 VOLTS CEC 600.-U Optional Solar Load Center NOTE: CEC 703.I0 requffes a permanent plaque or d1rectory denoting all electric pt)wer sources on or in the Ixemesls CAUTION MULTIPLE SOURCES OF POWER DISCONNECTS LOCATED AS SHOWN WARNING ELECTRIC SHOCK HAZARD TERMINALS ON BOTH THE LINE AND LOAD SIDES MAY BE ENERGIZED IN THE OPEN POSITION CALZONA SOLAR ENPHASE MICROINVERTERS FULLY MEET RAPID SHUTDOWN REQUIREMENTS IN THE NEW CODE WITHOUT THE NEED TO INSTALL ANY ADDITIONAL ELECTRICAL EQUIPMENT no" j" WARNiN ELECTRIC SH OCK HAZARD THE DC CONDUCTORS OF THIS PHOTOVOLTAIC SYSTEM ARE UNGROUNDED AND MAY BE ENERGMED LABEL LOCATION DC DISCONNECT,INVERTEP [PER CODE: GEC 690.41;] [To be used 'w when :nverte - : ungro .ended] WARNING ELECTRIC SHUCK HAZARD DO NOT TOUCH TER1,11NALS OFT 7A 0 TERMINALS 014 BOTH LUNE .414D LOAD SIDES MAY BE ENERGIZED IN THE OPEPi POSITION DC VOLTAGE IS ALWAYS PRESENT WHEN SOLAR MODULES ARE EXPOSED TO SUNLIGHT LABEL LOCATION AC DISGONNECT,POINT OF INTERCONNECTION [PER CODE: CE-C 690.13 (g)] WARNING ELECTRIC SH OCIC HAZARD DO NOT TOUCH TERMINALS TERMINALS ON BOTH LINE AND LOAD SIDES MAYBE ENERGaED IN THE OPEN POSITION LABEL LOCATION AC DISGDNNECT,POINT OF INTERCONNECTION [PER CODE: CEC 690,13(8 )14 1 II 1 • LABEL LOCATION INVERTER, JUNCTION BONES; ROOF), AC DISCONNECT [PER CODE: CEC 690.131 LABEL LOCATION CON DUIT, COMBINER BOX [PER CODE: CEC690.31(G)(3)] ALL PLACARDS SHALL BE OF WEATHER PROM CONSTRUCTION, BACKGROLND ON ALL PLACARDS SHALL BE RID WITH WHITE LETTERING U.O.N. PLACARD SI-ALL BE MOUNTED DIRErTLV ON THE EXISTING UTMM ELECTRICAL SERVICE. FAS-ENSts APPROVED BY 1ME LOAM AMMICTIOV LADCL LL1L.H 4 IV" IMM-ER [PER MIX; CK 690.56:Ci C 3 )] THE MAIM TMS F41WL HAS BEEN -CBWAKENJR �41 a 1 Dn NnT IN -WAN S FR RRFAKER LASL_ LDC.A-ff-A MAIN RV-1 PArEL -DNLV WVKh DE-"TE Fl1E MIN BREAKER REQUIRED PV SIGNAGE LABEL LOCATION AC DISCONNECT . POINT OF INTERCONNECT ION [PER CODE: CEC 690.54] LABEL LOCATION IPOTW OF TNTFRCYIAINF-nnN (PER CODE: CEC 705.12(2)ib) %n X"as / Pens Aors s stet r_t We eam ..- scoss -wf.p most ewl 1-1 ewoo 0u=10.ry J'AUTION'. SO LAR CIRCUIT LABEL LOCAT:O% MARKINGS PLACED ON ALL INTERIOR AND EkTEFIOR DC CONI)UIT, RACEWAYS, ENCLOSURES AND CABLE ASSEMBLES AT LEAST EVERY i n FT, AT -I JRNS ANn ARnvF,tAF1 nw PFN9TRATt?NS Mn Al I COMSINER�JUNCTION EOXES. (PER CODE: IF0605.11.1.4'1 LABEL LOCATION DISCONNECT, POINT OF INTERCONNECTION [PER CODE: CFC690.13(B)] DUAL POWER SOURCE SECOND SOURCE IS PHOTOVOLTAIC SYSTEM LABEL LOCATION POINT OF INTERCONNECTION [PER CODE: CK705,12(D)(4)] CAUTION: SOLAR ELECTRIC SYTTFM C ONNUC:TFn LABEL LOCAT10 % WEATHER RESISTANT MATERIAL, DURABLE ADHESDIVE, UL969 AS STANDARD TO WEATHER RATING (UL LISTING OF MARKINGS NOT REQUIRED), MIN -%- LETTER HEIGHT AKIAL UK 5AM1LAK t-ur f NV4-t5ULL,KALxU W1 It-Uh THE MAIN SERVICE DISCONNECT, PLACED ON THE OUTSIDE OF THE COVER WHEN DISCONNECT IS OPERATEC° WITH THE SERVICE PANEL CLOSED. (PER CODE: CEC690.15 ,690.13(9)) SOLAR PV SYSTEM EQUIPPED WITH RAPID SHUTDOWN TURN RAPID SHUTDOWN SWffC i TO THE OFF- P0S1'T1ON TO sP " SHUT DOWN PV SYSTM AND REDUCE SHOCK HAZARD IN TlC ARMY LABEL LOCATION AC DISCONNECT, DC DISCONNECT,'OINT OP PITERCONNECTION (PER CODE: CEC&X.56(CW I XA)) of 1.11 W461 Class: C46 9 N ,4,T�92878 WC Pa�e1) 707-6537 SAPP PHOTOVOLTAIC SOLAR SYSTEM 23 10 N 5PURGEON 5T 5ANTA ANA,CA,9270G � ISSUE DATE: 6/1 /2025 REV.: DATE:=DESCRIPTION: BY:-7 ri i9'KiT CH EL5EA AND CARTER 5APP APN#0030G I I 23 10 N 5PURGEON 5T 5ANTA ANA,CA,9270G TEL(7GO)-473-G2G5 -DRAWN BY: CHK.: APV.: MR MR MR :STAMP: Kev-i.� La f Fe-�h� KEVI N LAFEERTY CONTRACTOR C4G EET SIGNAGE :SHEET NUMBER: SHEET NUMBER E3 Expedited Permit Process for PV Systems - Micro-Inverter1 Expedited Permit Process for PV Systems Micro-Inverter The Solar America Board for Codes and Standards (Solar ABCs) Expedited Permit Pro- cess provides a means to differentiate systems that can be permitted quickly and easily due to their similarity with the majority of small-scale PV systems. Those systems with unique characteristics may be handled with small additions to this Expedited Permit Process or may require much more information, depending on the uniqueness of the installation. The following pages contain forms for the Micro-Inverter to use with the Expedited Per- mit Process. The Standard String, AC Module, and Supply-Side Connection forms are also available as interactive PDF files at www.solarabcs.org/permitting. In jurisdic- tions that have adopted the Expedited Permit Process for PV Systems, these forms can be filled out electronically and submitted in either printed form and via email. An elec- tronic format is used so that the supplied information is standardized and legible for the local jurisdiction. Expedited Permit Process for PV Systems — Micro-Inverter 2 Expedited Permit Process for Small-Scale PV Systems Micro-Inverter The information in this guideline is intended to help local jurisdictions and contractors identify when PV system installations are simple, needing only a basic review, and when an installation is more complex. It is likely that 50%-75% of all residential systems will comply with these simple criteria. For projects that fail to meet the simple criteria, resolution steps have been suggested to provide as a path to permit approval. Required Information for Permit: 1. Site plan showing location of major components on the property. This drawing need not be exactly to scale, but it should represent relative location of components at site (see supplied example site plan). PV arrays on dwellings with a 3’ perimeter space at ridge and sides may not need separate fire service review. 2. Electrical diagram showing PV array configuration, wiring system, overcurrent protection, inverter, disconnects, required signs, and ac connection to building (see supplied standard electrical diagram). 3. Specification sheets and installation manuals (if available) for all manufactured components including, but not limited to, PV modules, inverter(s), combiner box, disconnects, and mounting system. Step 1: Structural Review of PV Array Mounting System Is the array to be mounted on a defined, permitted roof structure? l Yes l No If No due to non-compliant roof or a ground mount, submit completed worksheet for the structure WKS1. Roof Information: 1. Is the roofing type lightweight (Yes = composition, lightweight masonry, metal, etc…)__________________________ ____________________________________________________________________________________________________ If No, submit completed worksheet for roof structure WKS1 (No = heavy masonry, slate, etc…). 2. Does the roof have a single roof covering? l Yes l No If No, submit completed worksheet for roof structure WKS1. 3. Provide method and type of weatherproofing roof penetrations (e.g. flashing, caulk).____________________________ Mounting System Information: 1. Is the mounting structure an engineered product designed to mount PV modules with no more than an 18” gap beneath the module frames? l Yes l No If No, provide details of structural attachment certified by a design professional. 2. For manufactured mounting systems, fill out information on the mounting system below: a. Mounting System Manufacturer ___________Product Name and Model#________________________________ b. Total Weight of PV Modules and Rails ___________lbs c. Total Number of Attachment Points____________ d. Weight per Attachment Point (b÷c)_________________lbs (if greater than 45 lbs, see WKS1) e. Maximum Spacing Between Attachment Points on a Rail ______________inches (see product manual for maximum spacing allowed based on maximum design wind speed) f. Total Surface Area of PV Modules (square feet)_________________ ft2 g. Distributed Weight of PV Module on Roof (b÷f)_______________ lbs/ft2 If distributed weight of the PV system is greater than 5 lbs/ft2, see WKS1. Step 2: Electrical Review of PV System (Calculations for Electrical Diagram) In order for a PV system to be considered for an expedited permit process, the following must apply: 1. PV modules, utility-interactive inverters, and combiner boxes are identified for use in PV systems. 2. The PV array is composed of 4 series strings or less per inverter. 3. The total inverter capacity has a continuous ac power output 13,440 Watts or less 4. The ac interconnection point is on the load side of service disconnecting means (690.64(B)). 5. One of the standard electrical diagrams (E1.1, E1.1a, E1.1b, or E1.1c) can be used to accurately represent the PV system. Interactive PDF diagrams are available at www.solarabcs.org/permitting. Fill out the standard electrical diagram completely. A guide to the electrical diagram is provided to help the applicant understand each blank to fill in. If the electrical system is more complex than the standard electrical diagram can effectively communicate, provide an alternative diagram with appropriate detail. E x p e d i t e d P e r m i t P r o c e s s f o r P V S y s t e m s 3 Micro-Inverter Site Plan E x p e d i t e d P e r m i t P r o c e s s f o r P V S y s t e m s 4 Micro-Inverter Electrical Diagram Contractor Name, Address and Phone:One-Line Standard Electrical Diagram for Micro-Inverter PV Systems Site Name: Site Address: System AC Size: SIZE FSCM NO DWG NO REV E1.1a SCALE NTS Date: SHEET Drawn By: Checked By: DESCRIPTION OR CONDUCTOR TYPE USE-2 or PV WIRE GEC EGC X ALL THAT APPLY EXTERIOR CABLE LISTED W/ INV. THWN-2 or XHHW-2 or RHW-2 GEC EGC X ALL THAT APPLY NO DC GEC IF 690.35 SYSTEM THWN-2 or XHHW-2 or RHW-2 GEC EGC X ALL THAT APPLY TAG 1 2 3 4 5 CONDUIT AND CONDUCTOR SCHEDULE COND. GAUGE MFG MFG NUMBER OF CONDUCTORS MFG Cable MFG Cable CONDUIT TYPE N/A N/A N/A SAME SAME CONDUIT SIZE N/A N/A N/A SAME SAME DESCRIPTION PV DC or AC MODULE DC/AC INVERTER (MICRO) J-BOX (IF USED) PV ARRAY AC COMB. PANEL (IF USED) GEN METER (IF USED) AC DISCONNECT (IF USED) SERVICE PANEL TAG 1 2 3 4 5 6 7 8 PART NUMBER NOTES FOR UNUSED MODULES PUT "N/A” in BLANK ABOVE 1 1 3 2 3 EQUIPMENT SCHEDULE 2 _____ MICRO-INVERTERS IN BRANCH- CIRCUIT MOD ____ DC AC MOD ____ DC AC MOD ____ DC AC MOD ____ DC AC MOD ____ DC AC MOD ____ DC AC J-BOX 4 AC DISCO M BUILDING GROUNDING ELECTRODE G M UTILITY SERVICE MAIN SERVICE PANEL MAIN OCPD INVERTER OCPD 6 7 8 5 4 5 G SEE GUIDE APPENDIX D FOR INFORMATION ON MODULE AND ARRAY GROUNDING AC COMBINER PANEL G ____ MICRO-INVERTERS IN BRANCH- CIRCUIT E x p e d i t e d P e r m i t P r o c e s s f o r P V S y s t e m s 5 Contractor Name, Address and Phone:Notes for One-Line Standard Electrical Diagram for Single-Phase PV Systems Site Name: Site Address: System AC Size: SIZE FSCM NO DWG NO REV E1.2a SCALE NTS Date: SHEET Drawn By: Checked By: MAX POWER-POINT CURRENT (IMP) MAX POWER-POINT VOLTAGE (VMP) OPEN-CIRCUIT VOLTAGE (VOC) SHORT-CIRCUIT CURRENT (ISC) MAX SERIES FUSE (OCPD) MAXIMUM POWER (PMAX) MAX VOLTAGE (TYP 600VDC) VOC TEMP COEFF (mV/oC or %/oC ) IF COEFF SUPPLIED, CIRCLE UNITS MODULE MAKE MODULE MODEL PV MODULE RATINGS @ STC (Guide Section 5) MAX DC VOLT RATING MAX POWER @ 40oC NOMINAL AC VOLTAGE MAX AC CURRENT MAX OCPD RATING INVERTER MAKE INVERTER MODEL INVERTER RATINGS (Guide Section 4) 1) IF UTILITY REQUIRES A VISIBLE-BREAK SWITCH, DOES THIS SWITCH MEET THE REQUIREMENT? YES NO N/A 2) IF GENERATION METER REQUIRED, DOES THIS METER SOCKET MEET THE REQUIREMENT? YES NO N/A 3) SIZE PHOTOVOLTAIC POWER SOURCE (DC) CONDUCTORS BASED ON MAX CURRENT ON NEC 690.53 SIGN OR OCPD RATING AT DISCONNECT 4) SIZE INVERTER OUTPUT CIRCUIT (AC) CONDUCTORS ACCORDING TO INVERTER OCPD AMPERE RATING. (See Guide Section 9) 5) TOTAL OF ______ INVERTER OUTPUT CIRCUIT OCPD(s), ONE FOR EACH MICRO-INVERTER CIRCUIT. DOES TOTAL SUPPLY BREAKERS COMPLY WITH 120% BUSBAR EXCEPTION IN 690.64(B)(2)(a)? YES NO NOTES FOR INVERTER CIRCUITS (Guide Section 8 and 9): 1.) LOWEST EXPECT AMBIENT TEMPERATURE BASED ON ASHRAE MINIMUM MEAN EXTREME DRY BULB TEMPERATURE FOR ASHRAE LOCATION MOST SIMILAR TO INSTALLATION LOCATION. LOWEST EXPECTED AMBIENT TEMP ____oC 2.) HIGHEST CONTINUOUS AMBIENT TEMPERATURE BASED ON ASHRAE HIGHEST MONTH 2% DRY BULB TEMPERATURE FOR ASHRAE LOCATION MOST SIMILAR TO INSTALLATION LOCATION. HIGHEST CONTINUOUS TEMPERATURE ____oC 2.) 2009 ASHRAE FUNDAMENTALS 2% DESIGN TEMPERATURES DO NOT EXCEED 47oC IN THE UNITED STATES (PALM SPRINGS, CA IS 44.1oC). FOR LESS THAN 9 CURRENT-CARRYING CONDUCTORS IN ROOF-MOUNTED SUNLIT CONDUIT AT LEAST 0.5" ABOVE ROOF AND USING THE OUTDOOR DESIGN TEMPERATURE OF 47oC OR LESS (ALL OF UNITED STATES), a) 12 AWG, 90oC CONDUCTORS ARE GENERALLY ACCEPTABLE FOR MODULES WITH Isc OF 7.68 AMPS OR LESS WHEN PROTECTED BY A 12-AMP OR SMALLER FUSE.b) 10 AWG, 90oC CONDUCTORS ARE GENERALLY ACCEPTABLE FOR MODULES WITH Isc OF 9.6 AMPS OR LESS WHEN PROTECTED BY A 15-AMP OR SMALLER FUSE. NOTES FOR ARRAY CIRCUIT WIRING (Guide Section 6 and 8 and Appendix E): OCPD = OVERCURRENT PROTECTION DEVICE NATIONAL ELECTRICAL CODE®REFERENCES SHOWN AS (NEC XXX.XX) NOTES FOR ALL DRAWINGS: SIGNS–SEE GUIDE SECTION 7 SIGN FOR DC DISCONNECT SIGN FOR INVERTER OCPD AND AC DISCONNECT (IF USED) No sign necessary since 690.51 marking on PV module covers needed information AC OUTPUT CURRENT NOMINAL AC VOLTAGE SOLAR PV SYSTEM AC POINT OF CONNECTION THIS PANEL FED BY MULTIPLE SOURCES (UTILITY AND SOLAR) Notes for Micro-Inverter Electrical Diagram To Whom It May Concern: CITY OF SANTA ANA Planning and Building Agency Approved FOR PERMIT ISSUANC Date: I give Caizona Solar permission to install a 6KW Solar Electric (PV) system consisting of 15 panels at my property located at 2312 N Spurgeon St, Santa Ana, CA 92706. o cke ll eks c�K Rev: 7/15/2021 RESIDENTIAL PHOTOVOLTAIC SOL-01 CBC 2019 Solar Photovoltaic (PV) Checklist for Detached SINGLE FAMILY RESIDENCES Only Instructions: The licensed contractor of record shall complete all sections, answer the ten questions and sign the certification section below. A copy of this form shall be attached to each of TWO sets of plans, of minimum 11” x 17” size. If answering NO to any of the questions, plan check shall be required. Project Address: Contractor Company Name: Contractor License Number: YES NO Are the following applicable to the proposed project? 1. Will the PV system layout provide the required three-foot wide clear access pathways per Section 605.11 of the California Fire Code, and is this shown on the roof plan? 2. Will the PV system be installed on a roof having only one roofing layer with no overlays? 3. Will the PV array be flush mounted to the existing roof so that the plane of the modules (panels) are parallel to the plane of the roof? 4. Will the PV system weigh maximum 4 pounds per square feet or less? 5. Will the PV system be installed where the modules do not overhang any roof edges (such as eaves, gabled ends, ridges and hips)? 6. Will the PV system be installed with a space of 2” minimum to 10” maximum between the underside of modules and the surface of the roof? 7. Will the PV system be installed without using any ballast system or counter-weight system? 8. Will the anchors be installed with a maximum horizontal anchor spacing of 6 feet and is this maximum horizontal spacing shown on the plans? 9. Will the minimum 5/16” lag screws be installed with a minimum of 2-1/2 inch embedment into roof rafters (with pre-drilled holes) and is this minimum embedment shown on the plans? 10. Are ALL the structural pages of the plans stamped and signed by a California licensed professional engineer? (including project specific site plan, PV layout, anchorage spacing, anchorage details and manufacturer’s PV support information.) I certify under penalty of perjury under the laws of the State of California that the above is true: Print Name: Signature: Phone Number: Date: Email Address: Planning & Building Agency Building Safety Division 20 Civic Center Plaza P.O. Box 1988 (M-19) Santa Ana, CA 92702 (714) 647-5800 www.santa-ana.org 2312 SPURGEON SANTA ANA,CA,92703 1064904 Calzona Solar x x x x x x x x x x 9517076537 8.4.25 dennishurtado009@outlook.com Kevin Lafferty Kevin Lafferty Hi-M( L R5-54 F 390^ • Suitable for distr • Advanced modu module efficient • M10 Gallium -doped Wak • GloballyvalidatE • High module qu; earWa rra Materials andd F 30 30-year Warran Linear Power C Complete System anc Product Certification! IEC 61215, IEC 61730, UL 6173( IS09001:2015:ISO Quality Mar ._o_...____,_ _.. IS014001: 2015: ISO Environment Management System IS045001: 2018: Occupational Health and Safety JEC62941: Guideline for module design qualification and type approval ■ LONGI CsAUs C E jff5 21.3% 0, MAX MODULE PI EFFICIENCY TOL Additional 30-Year Power Warranty 103% 91.2% +4.00% �\ 87.7Mo +4.95^(0 84.5% +6.50% 80.7% 1 7 10 in 20 25 30 Mechanical Parameters CITY OF SANTA ANA Planning and Building Agency LR5-54HA 3B 390-415M • - - NCE Cell Orientation 108 (6x 18) Junction Box IP68, three diodes 4mm', ±1200mm Output Cable length can be customized Glass Dual glass, 2.0+1.6mm heat strengthened glass Frame Anodized aluminum alloy frame Weight 22.5kg Dimension 1722x1134x30mm Packa in 36 cs er allet/216 cs er20'GP/936 csor792 cs(Onl for USA) er4UHC Units: mm ••o mmm g g P P P P P P P Y P c A -A B-B Electrical Characteristics STC:AM1.5 1000W/m2 25°C NOCT:AM1.5 800W/m2 20°C 1m/s Test uncertainty for Pmax:±3ho Module Type LR5-54HABB-390M LR5-54HABB-395M LR5-54HABB-400M LR5-54HABB-405M LR5-54HABB-410M LR5-54HABB-415M Testing Condition STC NOCT STC NOCT STC NOCT STC NOCT STC NOCT STC NOCT Maximum Power (Pmax/W) 390 291.5 395 295.2 400 299.0 405 302.7 410 306.5 415 310.2 Open Circuit Voltage (Voc/V) 36.58 34.39 36.81 34.61 37.05 34.84 37.29 35.06 37.53 35.29 37.77 35.51 Short Circuit Current (Isc/A) 13.57 10.95 13.65 11.01 13.72 11.07 13.79 11.13 13.87 11.19 13.94 11.25 Voltage at Maximum Power (Vmp/V) 30.47 28.43 30.70 2&64 30.94 28.86 31.18 29.09 31.42 29.31 31.66 29.54 Current at Maximum Power (Imp/A) 12.80 10.26 12.87 10.31 12.93 10.36 12.99 10.41 13.05 10.45 13.11 10.50 Module Efficiency(%) 20.0 20.2 20.5 20.7 21.0 21.3 Electrical characteristics with different rear side power gain (reference to 40OW front) Pmax /W Voc/V Isc /A Vmp/V Imp /A Pmax gain 420 37.05 14.41 30.94 13.58 5% 440 37.05 15.09 30.94 14.22 10% 460 37.15 15.78 31.04 14.87 15% 480 37.15 16.46 31.04 15.52 20% 500 37.15 17.15 31.04 16.16 25% Operating Parameters Mechanical Loading Operational Temperature -40°C-+85°C Front Side Maximum Static Loading 5400Pa Power Output Tolerance 0 - 3% Rear Side Maximum Static Loading 2400Pa Voc a nd Isc Tolerance ±3% Hai Intone Test 25mm Hailstone at the speed of 23m/s Maximum System Voltage DC1500V (IEC/UL) Maximum Series Fuse Rating 30A Nominal Operating Cell Temperature 45±2°C Protection Class Class 11 Temperature Ratings (STC) Bifaciality 70±5% Temperature Coefficient of Isc +0.050%/°C UL Similar type 38 ` Temperature Coefficient of Voc -0.2650/o/°C Fire Rating IECClass C. Temperature Coefficient of Pmax -0.3400/o/°C 'Reference Standard: UL61730 Second. Edition, Dated October 28, 2022 Specifications included in this datasheet are No.8369 Shangyuan Road, Van Economic And subjectto change without notice. LONGi LONG' Technological Development Zone, Van, Shaanxi, China. reserves the right offinal interpretation. Web: www.iongi.com (20230112DraftV02) Only for North America IQ8 Series Microinverters Our newest IQ8 Microinverters are the industry’s first microgrid-forming, software- defined microinverters with split-phase power conversion capability to convert DC power to AC power efficiently. The brain of the semiconductor-based microinverter is our proprietary application-specific integrated circuit (ASIC) which enables the microinverter to operate in grid-tied or off-grid modes. This chip is built in advanced 55nm technology with high speed digital logic and has super-fast response times to changing loads and grid events, alleviating constraints on battery sizing for home energy systems. Part of the Enphase Energy System, IQ8 Series Microinverters integrate with the Enphase IQ Battery, Enphase IQ Gateway, and the Enphase App monitoring and analysis software. IQ8 Series Microinverters redefine reliability standards with more than one million cumulative hours of power-on testing, enabling an industry- leading limited warranty of up to 25 years. Connect PV modules quickly and easily to IQ8 Series Microinverters using the included Q-DCC-2 adapter cable with plug-n-play MC4 connectors. IQ8 Series Microinverters are UL Listed as PV Rapid Shut Down Equipment and conform with various regulations, when installed according to manufacturer’s instructions. Easy to install • Lightweight and compact with plug-n-play connectors • Power Line Communication (PLC) between components • Faster installation with simple two-wire cabling High productivity and reliability • Produce power even when the grid is down* • More than one million cumulative hours of testing • Class II double-insulated enclosure • Optimized for the latest high- powered PV modules Microgrid-forming • Complies with the latest advanced grid support** • Remote automatic updates for the latest grid requirements • Configurable to support a wide range of grid profiles • Meets CA Rule 21 (UL 1741-SA) requirements © 2022 Enphase Energy. All rights reserved. Enphase, the Enphase logo, IQ8 Microinverters, and other names are trademarks of Enphase Energy, Inc. Data subject to change. IQ8SE-DS-0001-01-EN-US-2022-03-17 * Only when installed with IQ System Controller 2, meets UL 1741. IQ8H-208V operates only in grid-tied mode. ** IQ8 Series Microinverters supports split phase, 240V. IQ8H-208 supports split phase, 208V only. DATA SHEET (1) The IQ8H-208 variant will be operating in grid-tied mode only at 208V AC. (2) No enforced DC/AC ratio. See the compatibility calculator at https://link.enphase.com/module-compatibility (3) Maximum continuous input DC current is 10.6A (4) Nominal voltage range can be extended beyond nominal if required by the utility. (5) Limits may vary. Refer to local requirements to define the number of microinverters per branch in your area. IQ8 Series Microinverters INPUT DATA (DC)IQ8-60-2-US IQ8PLUS-72-2-US IQ8M-72-2-US IQ8A-72-2-US IQ8H-240-72-2-US IQ8H-208-72-2-US 1 Commonly used module pairings2 W 235 – 350 235 – 440 260 – 460 295 – 500 320 – 540+295 – 500+ Module compatibility 60-cell/120 half-cell 60-cell/120 half-cell, 66-cell/132 half-cell and 72-cell/144 half-cell MPPT voltage range V 27 – 37 29 – 45 33 – 45 36 – 45 38 – 45 38 – 45 Operating range V 25 – 48 25 – 58 Min/max start voltage V 30 / 48 30 / 58 Max input DC voltage V 50 60 Max DC current3 [module Isc] A 15 Overvoltage class DC port II DC port backfeed current mA 0 PV array configuration 1x1 Ungrounded array; No additional DC side protection required; AC side protection requires max 20A per branch circuit OUTPUT DATA (AC)IQ8-60-2-US IQ8PLUS-72-2-US IQ8M-72-2-US IQ8A-72-2-US IQ8H-240-72-2-US IQ8H-208-72-2-US 1 Peak output power VA 245 300 330 366 384 366 Max continuous output power VA 240 290 325 349 380 360 Nominal (L-L) voltage/range4 V 240 / 211 – 264 208 / 183 – 250 Max continuous output current A 1.0 1.21 1.35 1.45 1.58 1.73 Nominal frequency Hz 60 Extended frequency range Hz 50 – 68 AC short circuit fault current over 3 cycles Arms 2 4.4 Max units per 20 A (L-L) branch circuit5 16 13 11 11 10 9 Total harmonic distortion <5% Overvoltage class AC port III AC port backfeed current mA 30 Power factor setting 1.0 Grid-tied power factor (adjustable)0.85 leading – 0.85 lagging Peak efficiency %97.5 97.6 97.6 97.6 97.6 97.4 CEC weighted efficiency %97 97 97 97.5 97 97 Night-time power consumption mW 60 MECHANICAL DATA Ambient temperature range -40ºC to +60ºC (-40ºF to +140ºF) Relative humidity range 4% to 100% (condensing) DC Connector type MC4 Dimensions (HxWxD)212 mm (8.3”) x 175 mm (6.9”) x 30.2 mm (1.2”) Weight 1.08 kg (2.38 lbs) Cooling Natural convection – no fans Approved for wet locations Yes Pollution degree PD3 Enclosure Class II double-insulated, corrosion resistant polymeric enclosure Environ. category / UV exposure rating NEMA Type 6 / outdoor COMPLIANCE Certifications CA Rule 21 (UL 1741-SA), UL 62109-1, UL1741/IEEE1547, FCC Part 15 Class B, ICES-0003 Class B, CAN/CSA-C22.2 NO. 107.1-01 This product is UL Listed as PV Rapid Shut Down Equipment and conforms with NEC 2014, NEC 2017, and NEC 2020 section 690.12 and C22.1-2018 Rule 64-218 Rapid Shutdown of PV Systems, for AC and DC conductors, when installed according to manufacturer’s instructions. IQ8SE-DS-0001-01-EN-US-2022-03-17 CITY OF SANTA ANA Planning and Building Agency Enphase IQ Combiner 3 MODEL NUMBER �/p� IQ Combiner 3 IQ Combiner 3 with Enphase IQ Envoy'" printed circuit board f inte rated• r�P'P A�d�T''V"' X-IQ-AM1-240-3 production metering (ANSI C12.20+/-0.5%)and optional* con ur t�rR[i4MbT+A-93WANCE ACCESSORIES and REPLACEMENT PARTS (not included, order separately) Enphase Mobile Connect'" CELLMODEM-03 (413/12-year data plan) CELLMODEM-01 (3G/5-year data plan) CELLMODEM-M1 (4G based LTE-M/5-year data plan) Consumption Monitoring* CT CT-200-SPLIT • Consumption monitoring is required for Enphase Storage Systems Wireless USB adapter COMMS-KIT-01 Circuit Breakers BRK-10A-2-240 BRK-15A-2-240 BRK-20A-2P-240 EPLC-01 XA-PLUG-120-3 Plug and play industrial grade cellular modem with data plan microinverters. (Available in the US, Canada, Mexico, Puerto where there is adequate cellular service in the installation an Split core current transformers enable whole home consum f to b0 Virgin Islands, metering (+/- 2.5%). Installed at the.IQ Envoy. For communications with Enphase Encharge' storage and Enphase Enpower' smart switch. Includes USB cable for connection to IQ Envoy or Enphase IQ Combiner'" and allows redundant wireless communication with Encharge and Enpower. Supports Eaton BR210, BR215, BR220, BR230, BR240, BR250, and BR260 circuit breakers. Circuit breaker, 2 pole, 10A, Eaton BR210 Circuit breaker, 2 pole, 15A, Eaton BR215 Circuit breaker, 2 pole, 20A, Eaton BR220 Power line carrier (communication bridge pair), quantity - one pair Accessory receptacle for Power Line Carrier in IQ Combiner 3 (required for EPLC-01) XA-ENV-PCBA-3 Replacement IQ Envoy printed circuit board (PCB) for Combiner 3 ELECTRICAL SPECIFICATIONS Rating System voltage Eaton BR series busbar rating Max. continuous current rating (output to grid) Max. fuse/circuit rating (output) Branch circuits (solar and/or storage) Max. continuous current rating (input from PV) Max. total branch circuit breaker rating (input) Continuous duty 120/240 VAC, 60 Hz 125 A 65 A 90 A Up to four 2-pole Eaton BR series Distributed Generation (DG) breakers only (not included) 64 A BOA of distributed generation / 90A with IQ Envoy breaker included Production Metering CT 200 A solid core pre -installed and wired to IQ Envoy MECHANICAL DATA Dimensions (WxHxD) Weight Ambient temperature range Cooling Enclosure environmental rating 49.5 x 37.5 x 16.8 cm (19.5" x 14.75" x 6.63"). Height is 21.06" (53.5 cm with mounting brackets). 7.5 kg (16.5 Ibs) -400 C to +460 C (-400 to 1150 F) Natural convection, plus heat shield Outdoor, NRTL-certified, NEMA type 3R, polycarbonate construction Wire sizes 20 A to 50 A breaker inputs: 14 to 4 AWG copper conductors • 60 A breaker branch input: 4 to 1/0 AWG copper conductors • Main lug combined output: 10 to 2/0 AWG copper conductors • Neutral and ground: 14 to 1/0 copper conductors Always follow local code requirements for conductor sizing. Altitude To 2000 meters (6,560 feet) INTERNET CONNECTION OPTIONS Integrated Wi-Fi 802.11b/g/n Ethernet Optional, 802.3, Cat5E (or Cat 6) UTP Ethernet cable (not included) Cellular Optional, CELLMODEM-01 (3G) or CELLMODEM-03 (4G) or CELLMODEM-M1 (4G based LTE-M) (not included) COMPLIANCE Compliance, Combiner UL 1741, CAN/CSA C22.2 No. 107.1, 47 CFR, Part 15, Class B, ICES 003 Production metering: ANSI C12.20 accuracy class 0.5 (PV production) Compliance, IQ Envoy UL 60601-1/CANCSA 22.2 No. 61010-1 To learn more about Enphase offerings, visit enphase.com D 2018 Enphase Energy. All rights reserved. Enphase, the Enphase logo. IQ Combiner 3, and other trademarks or service names are the trademarks of Enphase Energy, Inc. 2019-11-04 E N P H A S E. `� Rapid shutdown is built-in What’s new in NEC 2014? NEC 2014, Section 690.12 applies to PV conductors over 10 feet from the PV array and requires that the conductors power down to 30 volts and 240 volt-amperes within 10 seconds of rapid shutdown initiation. Enphase® Energy // Rapid Shutdown ® To learn more, visit enphase.com The 2014 edition of the National Electrical Code (NEC 2014) added new rapid shutdown requirements for PV systems installed on buildings. Enphase Microinverters fully meet rapid shutdown requirements in the new code without the need to install any additional electrical equipment. Enphase comes standard with rapid shutdown capability Residential Microinverter Commercial Microinverter All Enphase microin- verters, even those that were previously installed, inherently meet rapid shutdown requirements, no additional equipment or workarounds needed Enphase microinverters can safely shut down automatically, leaving only low-voltage DC electricity isolated to the PV module String inverters require work arounds for rapid shutdown Residential String Inverter Commercial String Inverter Work around. Specialized Rapid Shutdown electrical box installed on the roof within 10 feet of array. Work around. String inverter installed on roof, a hostile environment that string inverters are not built to live in.Work around. Shutoff switch that is easily accessible to first responders on the ground. Work around. Extra conduit in installation. TECHNICAL BRIEF © 2015 Enphase Energy Inc. All rights reserved. January 2015 1 NEC 2014 — Enphase System Code Compliance Overview This technical brief discusses new NEC 2014 requirements that apply to Enphase Microinverter Systems. It is useful for installers, electricians, and electrical inspectors or authorities having jurisdiction (AHJs) in understanding how code-compliance is handled where NEC 2014 is adopted. Main topics discussed in this document are: • NEC 2014 Section 690.12 Rapid Shutdown of PV Systems on Buildings • NEC 2014 Section 705.12 Point of Connection • NEC 2014 Section 690.11 DC Arc-Fault Circuit Protection NEC 2014 Section 690.12 Rapid Shutdown of PV Systems on Buildings Enphase Microinverter Systems fully meet the rapid shutdown requirement without the need to install additional electrical equipment. Properly labeling the PV system power source and rapid shutdown ability is required per NEC Section 690.56 (B) and (C). Solar electric PV systems with Enphase Microinverters have one utility-interactive inverter directly underneath each solar module, converting low voltage DC to utility grid-compliant AC. When the utility grid is available and the sun is shining, each microinverter verifies that the utility grid is operating within the IEEE 1547 requirements. Only then does it export AC power into the electric service for use by loads onsite or export power to the utility grid for others to use. When the utility grid has a failure, or the PV system AC circuits are disconnected from the utility service via an AC breaker, AC disconnect, or removal of the solar or main utility service meter, the microinverters stop producing AC power in fewer than six AC cycles. Enphase Microinverters are not capable of operating as an AC voltage source. This means that without an AC utility source, Enphase Microinverters are not able to energize connected wiring and no AC voltage or current can be injected into the inverter output circuits or the grid. When the AC utility source is removed from the inverter output circuits via any means, such as an AC breaker, AC disconnect or removal of the solar or main utility service meter, this equipment performs the rapid shutdown function per 690.12. With an Enphase Microinverter System this shutdown occurs well within the 690.12 required 10 seconds, and there are no other conductors energized more than 1.5 m (5 ft) in length inside a building or more than 3 m (10 ft) from a PV array. Code Reference 690.12 Rapid Shutdown of PV Systems on Buildings. PV system circuits installed on or in buildings shall include a rapid shutdown function that controls specific conductors in accordance with 690.12(1) through (5) as follows. (1) Requirements for controlled conductors shall apply only to PV system conductors of more than 1.5 m (5 ft) in length inside a building, or more than 3 m (10 ft) from a PV array. (2) Controlled conductors shall be limited to not more than 30 volts and 240 volt-amperes within 10 seconds of rapid shutdown initiation. (3) Voltage and power shall be measured between any two conductors and between any conductor and ground. (4) The rapid shutdown initiation methods shall be labeled in accordance with 690.56(B). (5) Equipment that performs the rapid shutdown shall be listed and identified. NEC 2014 — Enphase System Code Compliance © 2015 Enphase Energy Inc. All rights reserved. January 2015 4 Three-Phase 208/120 Volt Services Solution: The compliance solution for systems interconnected to three-phase systems is to defer to NEC 90.4. There are no three-phase AC AFCI detection devices in existence. Until backfeed capable three- phase AC AFCI circuit breakers become generally available, an AHJ is permitted to refer to 90.4, i.e., the previous code edition, NEC 2011. Additionally, the NEC 210.12 code intention for any AC AFCI protection is for single-phase applications in dwellings or dormitory units and not meant for three-phase applications, example: Code Reference 210.12 Arc-Fault Circuit-Interrupter Protection. … 210.12(A) Dwelling Units. All 120-volt, single-phase, 15- and 20-ampere branch circuits….. 210.12(B) Branch Circuit Extensions or Modifications — Dwelling Units. … 210.12(C) Dormitory Units. All 120-volt, single-phase, 15- and 20-ampere branch circuits Although Chapter 7 applies to “Special Conditions,” the industry must be able to supply generally available equipment that is safe to use and meets the requirements for these special applications. For 705.12(D) (6) this is not the case for three-phase applications as there are no listed three-phase AC AFCI detection devices available. NEC 2014 Section 690.11 DC Arc-Fault Circuit Protection This requirement is for direct current (DC) Arc-Fault Circuit protection and only applies to systems with DC voltages above 80 VDC. Enphase Microinverter systems are exempted from this requirement as they always operate well below 80 VDC. The requirement is basically unchanged from the NEC 2011, and it is unnecessary to add DC AFCI to an Enphase Microinverter System installation. Code Reference 690.11 Arc-Fault Circuit Protection (Direct Current). Photovoltaic systems with dc source circuits, dc output circuits, or both, operating at a PV system maximum system voltage of 80 volts or greater, shall be protected by a listed (dc) arc-fault circuit interrupter, PV type, or other system components listed to provide equivalent protection. NEC 2014 — Enphase System Code Compliance © 2015 Enphase Energy Inc. All rights reserved. January 2015 2 NEC 2014 Section 705.12 Point of Connection (AC Arc-Fault Protection) In this section we explain how to comply with NEC 2014 Section 705.12 Point of Connection when installing Enphase Energy Systems with: • Supply Side Connection • Load-Side Connection to Single-Phase 120/240 Volt Services • Three-Phase 208/120 Volt Services Supply Side Connection Solution: No AC AFCI (Arc-Fault Circuit Interrupter) protection is required. Code Reference 705.12 Point of Connection The output of an interconnected electric power source shall be connected as specified in 705.12(A), (B), (C) or (D). Since the operator “OR” is used to define connection types, the code seems to intend that if one criteria is met, for example (A), the other criteria are not applicable. Code Reference 705.12(A) Supply Side. An electric power production source shall be permitted to be connected to the supply side of the service disconnecting means as permitted in 230.82(6). The sum of the ratings of all overcurrent devices connected to power production sources shall not exceed the rating of the service. 705.12(B) Integrated Electrical Systems. … 705.12(C) Greater Than 100 kW. … 705.12(D) Utility-Interactive Inverters. … 230.82(6) lists solar photovoltaic systems as eligible for equipment permitted to be connected to the supply side of the service disconnecting means. Since Enphase Energy Systems are solar photovoltaic systems, a supply side connection of an Enphase System may be accepted by AHJs to fully meet Code section 705.12. Since 705.12(A) requirements are met, it seems logical that the 705.12(D) requirements for connections to the load-side of the service disconnect means are not applicable. Load-Side Connection to Single-Phase 120/240 Volt Services Solution: Refer to section 90.4 and the previous code edition, NEC 2011. No listed backfeed capable AC AFCI solutions or acceptable equipment to enclose the cable harness exist. Until such products are generally available from manufacturers, when making load side connections, complying with NEC 2014 Section 705.12 (D) (6) is achieved by discretionary guidance per NEC 2014 Section 90.4. This means to refer to the previous code edition NEC 2011 Section 705.12, where AC Arc-Fault Circuit Protection is not a requirement for utility-interactive inverters. NEC 2014 Code Reference 705.12(D) Utility Interactive Inverters. The output of a utility-interactive inverter shall be permitted to be connected to the load side of the service disconnecting means of the other source(s) at any distribution equipment on the premises. Where distribution equipment, including switchgear, switchboards, or panelboards, is fed simultaneously by a primary source(s) of electricity and one or more utility-interactive inverters, and where this distribution equipment is NEC 2014 — Enphase System Code Compliance © 2015 Enphase Energy Inc. All rights reserved. January 2015 3 capable of supplying multiple branch circuits or feeders, or both, the interconnecting provisions for the utility-interactive inverter(s) shall comply with 705.12(D)(1) through (D)(6). 705.12 (D) (4) Suitable for Backfeed. Circuit breakers, if backfed, shall be suitable for such operation. 705.12(D)(6) Wire Harness and Exposed Cable Arc-Fault Protection. A utility-interactive inverter(s) that has a wire harness or cable output circuit rated 240 V, 30 amperes, or less, that is not installed within an enclosed raceway, shall be provided with listed ac AFCI protection. This NEC 2014 code section allows connection of an electric power source to the load side of service disconnect means and requires that the “interconnecting provisions for the utility-interactive inverter(s) shall comply with 705.12(D)(1) through (D)(6)”. Since the Enphase system contains one or more microinverters, which are the utility-interactive inverter(s), this section applies when connecting a system to the load side of a service disconnecting means. 705.12(D)(6) specifically requires that exposed AC cable systems, such as the Enphase Engage Cable, which is not feasibly run in enclosed raceway, to be protected by listed AC Arc-Fault Circuit Interrupter (AC AFCI) functionality. Given that utility-interactive inverters cannot operate without a utility service source, the location of the AC AFCI protecting the cable must logically be applied at the utility source side of the circuit. AC AFCI circuit breakers are the commonly available devices for single-phase branch circuits. No suitable for backfeed AC AFCI circuit breakers exist. Since Enphase Microinverters are utility-interactive inverters that backfeed into the electrical service through the overcurrent protection device, any AC AFCI circuit breakers must be specifically backfeed capable, per 705.12(D)(4). If terminals of circuit breaker AFCIs are marked “Line” and “Load,” then the AFCI product is not backfeed capable. No UL standard for backfeed testing exists for AC AFCI circuit breakers. Furthermore, 705.12(D)(6) requires that ac AFCI protection must be ”listed.” For a product or product category to become “listed,” a standard safety test procedure, such as a UL standard, must exist. The testing standard for AFCI circuit breakers is UL1699, which currently does not have provisions for testing this product category for backfeed applications. It is clear, that the code requirement is ahead of new product availability. Summary Until suitable for backfeed and listed AC AFCI circuit breakers become generally available, an AHJ is permitted to refer to 90.4, i.e., the previous code edition, NEC 2011. Code Reference 90.4 Enforcement. This Code may require new products, constructions, or materials that may not yet be available at the time the Code is adopted. In such event, the authority having jurisdiction may permit the use of the products, constructions, or materials that comply with the most recent previous edition of this Code adopted by the jurisdiction. Certificate Certificate no. US 82140038 01 License Holder: Unirac Inc. 1411 Broadway NE Albuquerque NM 87102 USA Manufacturing Plant: Unirac Inc. 1411 Broadway NE Albuquerque NM 87102 USA Test report no.: USA- 31440029 001 Client Reference: John Nagyvary Tested to: Subject 2703 No. 2 (11-13-2012) Planning and Building Agency A roved F IT I11UAN1-1 TOVRheinland Master ID: Date: Certified Product: Module Rack Mounting System License Fee- Units Model Designation: SolarMount (SM) 7 Maximum Size of PV Module: 65" long and 39.125" wide Maximum System Voltage of PV Module: 1000 VDC Maximum overcurrent protection rating of PV Module: 30 A Fire Rating: Class A when installed with Type 1 fire rated modules, Type 2 fire rated modules,, Type 3 fire rated modules, Type 10 fire rated modules. (continued) 7 Appendix: 1,1-4 Licensed Test mark: TUVRheinland u3 Date of Issue (day/mo/yr) 19/12/2014 TUV Rheinland PTL. LLC, 2210 South Roosevelt Street, Tempe, Arizona 85282, Tel (480) 966-1700. Fax )775) 314-6458 Certificate Certificate no. US 82140038 02 License Holder: Unirac Inc. 1411 Broadway NE Albuquerque NM 87102 USA Manufacturing Plant: Unirac Inc. 1411 Broadway NE Albuquerque NM 87102 USA Test report no.: USA- 31440029 001 Client Reference: John Nagyvary Tested to: Subject 2703 No. 2 (11-13-2012 ) Planning and Building Agency roved F IT ISSUANCE TUVRheinland Master ID: Date: Certified Product: Module Rack Mounting System License Fee- Units (continued) 7 Modules Evaluated & Qualified for Mechanical Load: Trina Solar TSM-255PA05.08 Design Load: Positive = 112 psf, Negative = 50 psf Centrosolar TP6 250 SW and E 250B Design Load: Positive = 112 psf, Negative = 50 psf TSMC Solar TS-150C2 Design Load: Positive = 35 psf, Negative = 35 psf Modules from the same series with same frame are qualified if their area is less than or equal to test module area. (continued) Appendix: 1,1-4 Licensed Test mark: I A' TUVRheinland us 7 Date of Issue (day/mo/yr) 19/12/2014 TUV Rheinland PTL, LLC, 2210 South Roosevelt Street, Tempe. Anzona 85282, Tel (480) 966-1700. Fax (775) 314-8458 Certificate Certificate no. US 82140038 03 License Holder: Manufacturing Plant: Unirac Inc. Unirac Inc. 1411 Broadway NE 1411 Broadway NE Albuquerque NM 87102 Albuquerque NM 87102 USA USA Test report no.: USA- 31440029 001 Client Reference: John Nagyvary Tested to: Subject 2703 No. 2 (11-13-2012) Certified Product: Module Rack Mounting System (continued) Modules Evaluated & Qualified for Electrical Bonding: AU Optronics (BenQ Solar) PM Series Canadian Solar CSSA-M, CS6P-M, CS6P-P, CSX-P Centrosolar America C-Series, E-Series ET Solar ET AC Module, ET Module Hanwha SolarOne HSL 60 Hyundai Heavy Industries MG Series Kyocera KD-F Series LG Electronics Mono Neon, Mono X Phono Solar Technology All Standard Modules (continued) Appendix: 1,1-4 Licensed Test mark: .A . TIO V Rhain[Anrf us CITY nG SANTA ANA Planning and Building Agency roved F IT ISSUANC( TOVRheinlanLd Master ID:y Date: License Fee - Units 7 7 Date of Issue (day/mo/yr) 19/12/2014 TUV Rheinland PTL. LLC, 2210 South Roosevelt Street, Tempe, Arizona 85282, Tel (480) 966-1700, Fax (775) 314-6458 Certificate Certificate no. US 82140038 04 - License Holder. Manufacturing Plant: Unirac Inc. Unirac Inc. 1411 Broadway NE 1411 Broadway NE Albuquerque NM 87102 Albuquerque NM 87102 USA USA Test report no.: USA- 31440029 001 Client Reference: John Nagyvary Tested to: Subject 2703 No. 2 (11-13-2012) Certified Product: Module Rack Mounting System (continued) Modules Qualified for Electrical Bonding [continued] Renesola All 60-cell Modules Sharp ND240QCJ, ND240QCS, NDQ235F4 Suniva MV Series, OPTIMUS Series SunPower AC, E-Series, Sig Black, X-Series Suntech STP XXX Trina PD05, PA05 Yingli Panda'60, YGE 60 Yingli YGE-Z 60 Sun Edison / MEMC F-Series, R-Series SolarWorld SunModule Protect, SunModule Plus Appendix: 1,1-4 Licensed Test mark: A' TUVRheinland us Planning and Building Agency I A roved I F IT ISSUANC( TOVRheinland Master ID: Date: License Fee - Units 7 7 Date of Issue (day/mo/yr) 19/12/2014 TUV Rheinland PTL, LLC, 2210 South Roosevelt Street. Tempe, Arizona 85282. Tel (480) 966-1700, Fax (775) 314-6458 July 11, 2024 Unirac Attn: Engineering Services Department 1411 Broadway Boulevard NE Albuquerque, NM 87102-1545 TEL: (505) 242-6411 RE: ENGINEERING CERTIFICATION LETTER FOR THE UNIRAC SOLARMOUNT (SM) ROOF PV PANEL SUPPORT SYSTEM STATE: CALIFORNIA TECTONIC WORK ORDER #: 12557.18 The Unirac SOLARMOUNT (SM) Photovoltaic Panel Support System is a proprietary framed photovoltaic panel support system that is installed on a roof. Tectonic Engineering Consultants (Tectonic) has reviewed the SM design methodology along with the U-Builder tool; a Unirac online design tool. The review included the following SM products, SM Light, Heavy Duty, and Standard rail with both the standard and pro hardware. Tectonic has determined that the design is a rational approach and follows the structural requirements of the following reference documents: Codes/Standards: • 2021 International Building Code by International Code Council. • 2022 California Building Code, Title 24, Part 2 (Volumes 1 & 2). • ASCE/SEI 7-16 Minimum Design Loads for Buildings and Other Structures , by American Society of Civil Engineers with provisions from SEAOC PV-2-2017. • 2020 Aluminum Design Manual, by Aluminum Association. This letter certifies that the structural analysis of the racking members, connections, and components directly related to Unirac’s system are in compliance with the above codes. The design methodology is acceptable under components and cladding loads associated with the building’s roof structure when the system is installed in accordance with manufacturer specifications. If the loading criteria does not meet Unirac’s specifications, owner shall contact Unirac for a site-specific certification. Attachments approved for the SM system to the structure include the following and is installed per Unirac’s U-Builder report and installation guides: ▪ Shingle Roof: L-Foot Flashkit Pro, Standoffs, Flashloc Comp, Flash Loc Duo, and Flash Kit Pro SB Unirac State Letter-CA Tectonic WO#: 12557.18 July 11, 2024 page 2 of 2 ▪ Metal Roof: Standing Seam Attachments, PM-9000s, and PM Adjust Slotted ▪ Tile Roof: Solar hooks, Flashkit Tile Replacement (TR) The U-Builder Tool should be used under the responsible charge of a registered professional engineer required by the authority having jurisdiction. The design tool and Unirac do not evaluate the existing roof structure, or the PV panels themselves. See the construction and installation drawings and manuals for additional information provided by Unirac. Sincerely, Tectonic Michael Martin, P.E. Senior Project Manager 07/11/24 SM SOLARMOUNT INSTALLATION GUIDE PAGE GROUNDING LUG MOUNTING DETAILS: Details are provided for both the WEEB and Ilsco products. The WEEBLug has a grounding symbol located on the lug assembly. The Ilsco lug has a green colored set screw for grounding indication purposes. Installation must be in accordance with NFPA NEC 70, however the electrical designer of record should refer to the latest revision of NEC for actual grounding conductor cable size WEEBLUG CONDUCTOR - UNIRAC P/N 008002S: Apply Anti Seize and insert a bolt in the aluminum rail and through the clearance hole in the stainless steel flat washer. Place the stainless steel flat washer on the bolt, oriented so the dimples will contact the aluminum rail. Place the lug portion on the bolt and stainless steel flat washer. Install stainless steel flat washer, lock washer and nut. Tighten the nut until the dimples are completely embedded into the rail and lug. See product data sheet for more details, Model No. WEEB-LUG-6.7. ILSCO LAY-IN LUG CONDUCTOR - UNIRAC P/N 008009P: Alternate Grounding Lug - Drill and bolt thru both rail walls per table. See product data sheet for more details, Model No. GBL-4DBT. GROUNDING LUG - BOLT SIZE & DRILL SIZE GROUND LIG BOLT SIZE DRILL SIZE WEEBLug 7/16”N/A - Place in Top SM Rail Slot IlSCO Lug #10-32 7/32" • Torque value depends on conductor size. • See product data sheet for torque value. SYSTEM GROUNDING 18 SF SUN FRAME RM ROOF MOUNT UL2703 SYSTEM FIRE CLASSIFICATION CLASS A - TYPE 1, 2, 3 & 10 MODULES *TYPE 10 MODULES - SOLARMOUNT SYSTEM ONLY NO ADDITIONAL PARTS REQUIRED. BUSINESS AS USUAL. Unirac product lines do not require any additional parts or modifications to their existing system components to achieve a UL1703 and UL2703 Class A Rating / Fire Certification. Enjoy the same great labor savings with no additional component costs. Refer to each product’s Installation Guide and Design & Engineering Guide for specific details. BUILDING CODE REQUIREMENTS. TESTING / CERTIFICATION PROCESS. BUILDING CODE The International Building Code (IBC) 2012 has been adopted in serval states and includes new requirements for the fire classification of solar systems. These requirements are included in Chapter 15 – Roofing. The IBC applies to commercial buildings and in some instances residential buildings. IBC 2012 has been adopted by the State of California and the new requirements for the fire classification of solar systems will be effective January 2015. CERTIFIED STANDARDS UL 1703 and 2703 have been updated to reflect the new requirements in the IBC 2012. The testing requirements include: • Module Typing (Types 1 and 2 are the most common; Type 3 and 10 refer to Glass – Glass modules or ThinFilm modules) • Spread of Flame Testing (System = Module + Mounting) • Burning Brand Testing (System = Module + Mounting) WHAT YOU NEED TO KNOW 1. Check with your local AHJ to determine the required roof classification of your building. The fire classification of the solar system will need to match or be greater than the roof classification. 2. Check to see what “Type of Module” you are purchasing. 3. Check to see if your mounting system has been tested with this “Type of Module”, what fire classification was achieved, and if any additional components or installation requirements are needed. This information should be included in the mounting manufacturer’s installation instructions and certification documentation. 4. Provide the mounting manufacturer’s installation instructions and certification documentation to your AHJ for approval. QUESTIONS Info@unirac.com SM SOLAR MOUNT CLASS A - TYPE 1, 2, 3 & 10 MODULES CLASS A - TYPE 1, 2 & 3 MODULES CLASS A - TYPE 1, 2 & 3 MODULES ROOF COVERING FIRE CLASS RATING MOUNTING SYSTEM MODULE TYPE CLASSICATION COMPONENTS BURNING BRAND TEST(Pitched Roof Only) A burning wood block is placed on module as a fan blows at 12 MPH. The flame can’t be seen on the underside of the roof within 90 minutes Flame at southern edge of roof is aimed up the roof as a fan blows at 12 MPH. The flame can’t spread 6 feet or more in 10 mins. SPREAD OF FLAME TEST TESTING PROCEDURES © DIGITAL PUB 150101 FLASHLOC is the ultimate attachment for composition shingle and rolled comp roofs. The all-in-one mount installs fast — no kneeling on hot roofs to install flashing, no prying or cutting shingles, no pulling nails. Simply drive the lag bolt and inject sealant into the base. FLASHLOC’s patented TRIPLE SEAL technology preserves the roof and protects the penetration with a permanent pressure seal. Kitted with lag bolts, sealant, and hardware for maximum convenience. Don’t just divert water, LOC it out! PROTECT THE ROOF Install a high-strength waterproof attachment without lifting, prying or damaging shingles. FLASH LOC LOC OUT WATER With an outer shield 1 contour-conforming gasket 2 and pressurized sealant chamber 3 the Triple Seal technology delivers a 100% waterproof connection. Cut Away View HIGH-SPEED INSTALL Simply drive lag bolt and inject sealant into the port 4 to create a permanent pressure seal. Cut Away View FASTER INSTALLATION. 25-YEAR WARRANTY. FOR QUESTIONS OR CUSTOMER SERVICE VISIT UNIRAC.COM OR CALL (505) 248-2702 3 2 4 1 TESTED TO TAS-100 WIND DRIVEN RAIN TEST AND UL441 RAIN TEST JUNE2021_FLASHLOCCOMP_V2 FASTER INSTALLATION. 25-YEAR WARRANTY. FOR QUESTIONS OR CUSTOMER SERVICE VISIT UNIRAC.COM OR CALL (505) 248-2702 FLASH LOC INSTALLATION GUIDE STEP 1: SECURE Place FLASHLOC over pilot hole with lag on down-slope side. Align indicator marks on sides of mount with chalk line. Pass included lag bolt and sealing washer through FLASHLOC into pilot hole. Drive lag bolt until mount is held firmly in place. NOTE: The EPDM in the sealing washer will expand beyond the edge of the metal washer when proper torque is applied. PRE-INSTALL Snap chalk lines for attachment rows. On shingle roofs, snap lines 1-3/4” below upslope edge of shingle course. Locate rafters and mark attachment locations. At each location, drill a 7/32” pilot hole. Clean roof surface of dirt, debris, snow, and ice. Next, BACKFILL ALL PILOT HOLES WITH SEALANT. NOTE: Space mounts per racking system install specifications. STEP 2: SEAL Insert tip of UNIRAC provided sealant into port. Inject until sealant exits both vents. Follow sealant manufacturer’s instructions. Follow sealant manufacturer’s cold weather application guidelines, if applicable. Continue array installation, attaching rails to mounts with provided T-bolts. NOTE: When FLASHLOC is installed over gap between shingle tabs or vertical joints, fill gap/joint with sealant between mount and upslope edge of shingle course. USE ONLY UNIRAC APPROVED SEALANTS: Chemlink Duralink 50, Chemlink M-1, Geocel 4500, or Geocel S-4 SEALANT GAP 1.75" CITY OF SANTA ANA Planning and Building Agency Lntortch k Total Quality. Assured. UNIRAC, INC. I .- ES*1 Rl�-Voei. SCOPE OF WORK UL 441, SECTION 27: RAIN TEST TESTING ON FLASHLOC, ROOF MOUNT REPORT NUMBER K1190.01-109-44 TEST DATE(S) 09/04/19 - 09/09/19 ISSUE DATE 09/19/19 RECORD RETENTION END DATE 09/09/23 PAGES 15 DOCUMENT CONTROL NUMBER ATI 00479 (07/24/17) RT-R-AM ER-Test-2805 © 2017 INTERTEK Approved FOR PERMIT ISSUANCE Master ID: Date: U Intertek Total Quality. Assured. TEST REPORT FOR UNIRAC, INC. Report No.: K1190.01-109-44 Date: 09/19/19 UNIRAC, INC. 1411 Broadway Blvd. NE Albuquerque, New Mexico 87102-1545 SCOPE CITY OF SANTA ANA Planning and Building Agency 130 Derry ourt York, ennsylvaniaproved lepho e:F'0136P-OMIT ISSUANCE =acsim le: 717-764-4129 Master ID: Date: Intertek Building & Construction (B&C) was contracted by Unirac, Inc. to perform testing in accordance with UL 441 Section 27: Rain Test, on their FLASHLOC, Roof Mount. Results obtained are tested values and were secured by using the designated test method(s). Testing was conducted at Intertek B&C test facility in York, Pennsylvania. This report does not constitute certification of this product nor an opinion or endorsement by this laboratory. For INTERTEK B&C: COMPLETED BY: Robert J. Beatty REVIEWED BY: TimothyJ. McGill Technician — TITLE: Product Testing TITLE: Manager— Product Testing SIGNATURE: o19„yys191.aMRIxM811„y SIGNATURE: DATE: 09/19/19 DATE: 09/19/19 RJB:vvnl This report is for the exclusive use of Intertek's Client and is provided pursuant to the agreement between Intertek and its Client. Intertek's responsibility and liability are limited to the terms and conditions of the agreement. Intertek assumes no liability to any party, other than to the Client in accordance with the agreement, for any loss, expense or damage occasioned by the use of this report. Only the Client is authorized to permit copying or distribution of this report and then only in its entirety. Any use of the Intertek name or one of its marksforthe sale oradvertisement ofthe tested material, product or service must first be approved in writing by Intertek. The observations and test results in this report are relevant only to the sample(s) tested. This report by itself does not imply that the material, product, or service is or has ever been under an Intertek certification program. Version: 07/24/17 Page 2 of 15 RT-R-AMER-Test-2805 CITY OF SANTA ANA Planning and Building Agency untertek York, Rennsylvania4pproved 130 Derry Qourt Total Quality. Assured. Telepho e: FiQ&V" M IT ISSUANCE Facsim le: 717-764-4129 www.int2rtek.com/building TEST REPORT FOR UNIRAC, INC. Report No.: K1190.01-109-44 Master ID: Date: 09/19/19 Date: TEST METHOD(S) The specimens were evaluated in accordance with the following: U L 441 Eleventh Edition dated August 28, 2019, UL Standard for Safety for Gas Vents, Section 27: Rain Test MATERIAL SOURCE/INSTALLATION Test specimens were provided by the client. Representative samples of the test specimen(s) will be retained by Intertek B&C for a minimum of four years from the test completion date. Test Specimens #1 and #2 Deck Construction: The test deck measured 3' wide by 3' high and was constructed of #2 Spruce -Pine -Fir nominal 2x6 lumber. One stud was centered on the deck for bolt attachment. Studs were attached to the top and bottom plates with 3" long drywall screws. A sheet of nominal 1/2" thick plywood was secured to the studs with #8 x 1-5/8" drywall screws. Silicone was utilized on the backside of the test panel to seal the perimeter. The test deck was then covered with #30 felt paper and asphalt shingles. Test Specimen #3 and #4 Deck Construction: The test deck measured 3' wide by 3' high and was constructed of #2 Spruce -Pine -Fir nominal 2x6 lumber. One stud was centered on the deck for bolt attachment. Studs were attached to the top and bottom plates with 3" long drywall screws. A sheet of nominal 1/2" thick plywood was secured to the studs with #8 x 1-5/8" drywall screws. Silicone was utilized on the backside of the test panel to seal the perimeter. The test deck was then covered with torch applied roof membrane. Test Specimen Installation: Each specimen was centered on a 2x6 stud and was secured with a 5/16" x 4" hex head lag bolt with a stainless steel -back EPDM washer through the Flashloc Comp Mount into the stud. The Flashloc Comp Mounts were completely filled with sealant. Test Specimens #1 and #3 utilized DuraLinkTm 50 sealant. Test Specimens #2 and #4 utilized M-11 sealant. The sealant was allowed to cure for 24 hours. Version: 07/24/17 Page 3 of 15 RT-R-AMER-Test-2805 CITY OF SANTA ANA Planning and Building Agency Lntertek Total Quality. Assured. TEST REPORT FOR UNIRAC, INC. Report No.: K1190.01-109-44 Date:09/19/19 LIST OF OFFICIAL OBSERVERS NAME TimothyJ. McGill Robert J. Beatty TEST SPECIMEN DESCRIPTION Product Type: Roof Mount Series/Model: FLASHLOC COMPANY Intertek B&C Intertek B&C The following descriptions apply to all specimens. 130 Derry fourt York, ennsylvania proved ?lepho e:FQI36PQ3MIT ISSUANCE -acsi le: 717-764-4129 Nw.inlertek.com/building Master ID: Date: Test Specimen Description: The test specimens were formed from cast aluminum and measured approximately 3-3/4" (95 mm) wide by 2-1/4" (57.2 mm) high by 3-1/2" (88.9 mm) tall. (Reference Drawing Number P28503006) Version: 07/24/17 Page 4 of 15 RT-R-AMER-Test-2805 CITY OF SANTA ANA Planning and Building Agency tntertek Total Quality. Assured. TEST REPORT FOR UNIRAC, INC. Report No.: K1190.01-109-44 Date: 09/19/19 TEST RESULTS 130 Derryourt York, ennsylvanianpproved Telepho e:FQI36P-h(RMIT ISSUANCE Facsimile: 717-764-4129 Master ID: Date: The temperature during testing ranged from 777 (25°C) to 827 (28°C). The results are tabulated as follows: Test Specimen #1: TITLE OF TEST RESULTS ALLOWED NOTE Water Penetration per UL 441 One hour of water spray No leakage No leakage 1 Test Specimen #1: TITLE OF TEST RESULTS ALLOWED NOTE Water Penetration per UL 441 One hour of water spray No leakage No leakage 2 Test Specimen #2: TITLE OF TEST RESULTS ALLOWED NOTE Water Penetration per UL 441 One hour of water spray No leakage No leakage 1 Test Specimen #2: TITLE OF TEST RESULTS ALLOWED NOTE Water Penetration per UL 441 One hour of water spray No leakage No leakage 2 Test Specimen #3: TITLE OF TEST RESULTS ALLOWED NOTE Water Penetration per UL 441 One hour of water spray No leakage No leakage 1 Version: 07/24/17 Page 5 of 15 RT-R-AMER-Test-2805 CITY OF SANTA ANA Planning and Building Agency Lntertek Total Quality. Assured. TEST REPORT FOR UNIRAC, INC. Report No.: K1190.01-109-44 Date:09/19/19 Test Specimen #3: 130 Derry ourt York, ennsylvania proved Telepho e:F-0136UBMIT ISSUANCE Facsimile: 717-764-4129 Master ID: Date: TITLE OF TEST RESULTS ALLOWED NOTE Water Penetration per UL 441 One hour of water spray No leakage No leakage 2 Test Specimen #4: TITLE OF TEST RESULTS ALLOWED NOTE Water Penetration per UL 441 One hour of water spray No leakage No leakage 1 Test Specimen #4: TITLE OF TEST RESULTS ALLOWED NOTE Water Penetration per UL 441 One hour of water spray No leakage No leakage 2 General Note: All testing was performed in accordance with the referenced standard(s). Note 1: Tested at a 2:12 roof pitch. Note 2: Tested at a 12:12 roof pitch Version: 07/24/17 Page 6 of 15 RT-R-AMER-Test-2805 CITY OF SANTA ANA Planning and Building Agency ntertek Total Quality. Assured. TEST REPORT FOR UNIRAC, INC. Report No.: K1190.01-109-44 Date: 09/19/19 PHOTOGRAPHS 130 Derry Qpurt York, F ennsylvania pproved Telepho e: F-Qf36,P"MIT ISSUANCE Facsim le: 717-764-4129 Avww.int rtek.com/building Master ID: Date: _ .__,..—------- i r--f1h riiir nrrunarr«. . Photo No. 1 Test Specimen #1 Photo No. 2 Test Specimen #2 Version: 07/24/17 Page 7 of 15 RT-R-AMER-Test-2805 CITY OF SANTA ANA Planning and Building Agency u tofotek Total Quality. Assured. TEST REPORT FOR UNIRAC, INC. Report No.: K1190.01-109-44 Date:09/19/19 Photo No. 3 Test Specimen #3 Photo No. 4 Test Specimen #4 130 Derry ourt York, PennsylvaniApp roved �leph ne,jFQPv F7-AMIT ISSUANCE :acsi ile: 717-764-4129 Master ID: Date: Version: 07/24/17 Page 8 of 15 RT-R-AMER-Test-2805 u itertek York, Total Quality. Assured. Teleph, Pacsir www.ir TEST REPORT FOR UNIRAC, INC. Report No.: K1190.01-109-44 Date: 09/19/19 DRAWINGS CITY OF SANTA ANA Planning and Building Agency 130 Derry ourt insylvaniaAlp proved :FQP16K(RMIT ISSUANCE : 717-764-4129 Master ID: Date: The test specimen drawings have been reviewed by Intertek B&C and are representative of the test specimen(s) reported herein. Test specimen construction was verified by Intertek B&C per the drawings included in this report. Any deviations are documented herein or on the drawings. Version: 07/24/17 Page 9 of 15 RT-R-AMER-Test-2805 CITY OF SANTA ANA Planning and Building Agency tntertek 13lvania ourt York, ennsyvania�pproved Total Quality. Assured. Telephc ne:FOAR-F78MIT ISSUANCE Facsi ile: 717-764-4129 www.in ertek.com/building TEST REPORT FOR UNIRAC, INC. Master ID: Report No.: K1190.01-109-44 Date: Date: 09/19/19 REVISION LOG REVISION # DATE PAGES REVISION 0 09/19/19 N/A Original Report Issue Version: 07/24/17 Page 15 of 15 RT-R-AMER-Test-2805 Structural Calculations for a Roof Mounted Solar Photovoltaic System for: Carter Chelsea Sapp 2310 N Spurgeon St Santa Ana, CA 92706 Sht # 1 of 7 2025-1416 Calzona Solar Carter Chelsea Sapp June 6, 2025 Loyd W. Martin Professional Engineer, Inc. Exp. 3-31-19 C L 2187 Note to Building Official: Based upon a review of the proposed plans I am confident that the existing roof framing system is capable of safely supporting the additional loads caused by the new solar photovoltaic energy system. The contractor shall field verify that the existing roof structure is in its original permited condition and verify that it can support the normal code required roof live loads. Attached in this package are several calculations showing that the roof members can support the additional weight of the solar array. Furthermore, an analysis of the solar array's support for wind forces and a seismic analysis of the existing structure are also included. Check Existing 2X4 Roof Rafters @ 24" O.C.: (Assume max rafters span = 7.83 ft.) w =30 psf x 2 ft. = 60 plf Total load on rafters = 60 plf x 7.83 ft. = 470 lbs Sht # 2 of 7 2025-1416 Calzona Solar Carter Chelsea Sapp June 6, 2025 Loyd W. Martin Professional Engineer, Inc. 9924 Universal Boulevard #224-406 Orlando, FL 32819 Tel:1.310.464.1804 Email: loydwmartin@gmail.com www.loydwmartin.com 7.83' Exp. 3-31-19 C L 2187 Check Existing 2X4 Roof Rafters @ 24" O.C.: Snow Load =0 psf Dead Load =14 psf Live Load =16 psf WDL + LL =30 psf x 2 ft. = 60 plf WDL =14 psf x 2 ft. = 28 plf w =30 psf x 2 ft. = 60 plf Total load on rafters =( 60 plf x 1.5 ft ) + ( 28 plf x 6.33 ft ) + ( 6' x 1.65' x 3 psf x 4 ) =386 lbs < 470 lbs OK OK. Per 2022 California Existing Building Code Section 503.3 Alterations Check attachment of Support to Existing Structure for Wind Uplift CHECK SOLAR STRUCTURE ATTACHMENTS PER ASCE 7-16 WIND LOADS ON BUILDING APPURTENANCES AND OTHER STRUCTURES Section 29.4.4 THEREFORE CHECK ATTACHMENT FOR TYPICAL CRITICAL LOAD WHICH IS THE EDGE ZONE - ZONE 2. NOTE: PER DEFINITION ON SHEETS 246 & 247 OF ASCE 7-16 EFFECTIVE WIND AREA: FOR ROOFTOP SOLAR ARRAYS, THE EFFECTIVE WIND AREA IN FIG. 29.4-7 IS EQUAL TO THE TRIBUTARY AREA FOR THE STRUCTURAL ELEMENT BEING CONSIDERED, EXCEPT THAT THE WIDTH OF THE EFFECTIVE WIND AREA NEED NOT BE LESS THAN ONE-THIRD ITS LENGTH. EFFECTIVE AREA = 15 SQ FT Sht # 3 of 7 2025-1416 Calzona Solar Carter Chelsea Sapp June 6, 2025 Loyd W. Martin Professional Engineer, Inc. 9924 Universal Boulevard #224-406 Orlando, FL 32819 Tel:1.310.464.1804 Email: loydwmartin@gmail.com www.loydwmartin.com % CHANGE =386 lbs - 470 lbs x 100 =-17.9% < 5% OK470 lbs Exp. 3-31-19 C L 2187 Check attachment of Support to Existing Structure for Wind Uplift - Cont'd Tributary Area to Each Solar Mount = 6 ft. x 2.75 ft. = 16.5 sq. ft. ( Max ) Calculate Design Wind Pressure at each support (Wind Speed 130 mph Exposure C): p = q h (GC p )(γ E )(γ a )Eq'n 29.4-7 ASCE 7-16 q h = 0.00256 K z K zt K d K e V 2 Eq'n 26.10-1 ASCE 7-16 Note: K z =velocity pressure coefficient Section 29.10.1 ASCE 7-16 K z =0.9 (Exposure C, Height = 20 ft or less) K zt =Topographical Factor = 1.0 K d =Wind Directionality Factor = 0.85 K e =Ground Elevation Factor = 1.0 V =130 mph q h =0.00256 (0.9) (1.0) (0.85) (1.0) (130)² q h =33.1 psf GC p =-2.0 (Zone 2 ; Effective Area = 15 sq. ft. ) γ E =Exposure Factor = 1.5 γ a =Solar Array Pressure Equalization Factor = 0.7 Fig. 29.4-8 ASCE 7-16 p = q h (GC p )(γ E )(γ a ) p = 33.1 psf (-2.0) (1.5) (0.7) = 69.5 psf Sht # 4 of 7 2025-1416 Calzona Solar Carter Chelsea Sapp June 6, 2025 Loyd W. Martin Professional Engineer, Inc. 9924 Universal Boulevard #224-406 Orlando, FL 32819 Tel:1.310.464.1804 Email: loydwmartin@gmail.com www.loydwmartin.com Exp. 3-31-19 C L 2187 Check attachment of Support to Existing Structure for Wind Uplift - Cont'd Nominal (Unfactored) Uplift at each support = 69.5 psf x 16.5 sq. ft. = 1146.75 lbs Note: Section 2.4.1 of ASCE 7-16, Basic Load Combinations for Allowable Stress Design. Note: Applicable Load Combination #5 (D + 0.6W) Design (Factored) Uplift at each support = 0.6 x 1146.75 lbs = 688 lbs Load per lag screw = 688 lbs / 1 = 688 lbs Determine allowable load per 5/16" lag screw w/ 2.5" embedment into wood below according to the 2018 NDS. W ' = W x Cd x Ct Table 10.3.1 2018 NDS where W = 266 lbs / in. of embedment per Table 12.2a Cd = 1.6 per Table 2.3.2 of 2018 NDS Ct = 1.0 per Table 2.3.3 of 2018 NDS W' = 266 lbs/ in. x 2.5 in. x 1.6 x 1.0 = 1,064 lbs > 688 lbs OK Sht # 5 of 7 2025-1416 Calzona Solar Carter Chelsea Sapp June 6, 2025 Loyd W. Martin Professional Engineer, Inc. 9924 Universal Boulevard #224-406 Orlando, FL 32819 Tel:1.310.464.1804 Email: loydwmartin@gmail.com www.loydwmartin.com Use Support connected to 2x Min. Roof Member w/ (1) 5/16" x 3.5" lag screws per connection minimum. Exp. 3-31-19 C L 2187 Check Seismic load due to added dead load of photovoltaic system. Determine Seismic Weight of Existing Building: Effective Existing Seismic Weight Area of (E) Building =Approximately 700 Sq. ft Approximate Effective =700 sq. ft. x 30 psf ave. = 21,000 LBS Seismic Weight DETERMINE BASE SHEAR V = Cs W EQ'N 12.8-1 ASCE 7-16 EQ'N 12.8-2 ASCE 7-16 R = THE RESPONSE MODIFICATION FACTOR IN TABLE 12.2-1 R =6.5 WOOD SHEAR WALLS Ie = 1.0 IMPORTANCE FACTOR SDS = 2/3 x SMS SMS = FA x SS SMS = 1.2 x 1.5 = 1.8 SDS = 2/3 x 1.8 = 1.2 Cs ==0.185 EQ'N 12.8-2 ASCE 7-16 Sht # 6 of 7 2025-1416 Calzona Solar Carter Chelsea Sapp June 6, 2025 Loyd W. Martin Professional Engineer, Inc. 9924 Universal Boulevard #224-406 Orlando, FL 32819 Tel:1.310.464.1804 Email: loydwmartin@gmail.com www.loydwmartin.com Cs =SDS R Ie SDS R Ie Exp. 3-31-19 C L 2187 EXISTING BASE SHEAR V = 0.185 x 21,000 LBS = 3,885 LBS DETERMINE NEW BASE SHEAR Determine Seismic Weight of Building with Solar Array: EXISTING SEISMIC =21,000 LBS WEIGHT NEW SOLAR ARRAY =3 PSF x 15 PANELS x 5.5' x 3.3' = 817 LBS NEW SEISMIC =21,000 LBS + 817 LBS = 21,817 LBS WEIGHT THEREFORE NEW BASE SHEAR: V = 0.185 x 21,817 = 4,037 LBS EQ'N 12.8-1 ASCE 7-16 OK. PER ASCE 7-16 SECTION 11B.4 ALTERATIONS EXISTING LATERAL FORCE RESISTING SYSTEM IS EXEMPT FROM ANALYSIS SINCE NEW SEISMIC FORCE IS LESS THAN 10% GREATER THAN EXISTING SEISMIC FORCE Sht # 7 of 7 2025-1416 Calzona Solar Carter Chelsea Sapp June 6, 2025 Loyd W. Martin Professional Engineer, Inc. 9924 Universal Boulevard #224-406 Orlando, FL 32819 Tel:1.310.464.1804 "Alterations may be made to any structure without requiring the existing structure to comply with this standard, provided that the alterations comply with the requirements for a new structure. Alterations that increase the seismic force in any existing structural element by more than 10% or decrease the design strength of any existing structural element to resist seismic forces by more than 10% shall not be permitted unless the entire seismic force- resisting system is determined to comply with this standard for a new structure." End of Calculations Email: loydwmartin@gmail.com www.loydwmartin.com % CHANGE =4,037 LBS - 3,885 LBS x 100 = 3.9 % < 10 % OK3,885 LBS Exp. 3-31-19 C L 2187