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Home My WebLink About2319 N Flower St - PlanBldg Permit #101110288 Elect Permit #20176065 Issued on 5-11-22 2319 N Flower 05/17/22 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. 2319 N Flower 05/17/22 Expedited Permit Process for PV Systems — Micro-Inverter2 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)_________________ ft 2 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. 2319 N Flower 05/17/22 Ex 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                                                        TENCO SOLAR - CSL#820684 SATKIN, PAUL 18340 YORBA LINDA BLVD#107-497 YORBA LINDA,CA, 92886 2319 N FLOWER ST 949) 795-3472 DC:3.6 AC:3.287kW 2319 N Flower 05/17/22 Ex 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 TENCO SOLAR - CSL#820684 18340 YORBA LINDA BLVD#107-497 YORBA LINDA,CA, 92886 SATKIN, PAUL DC:3.6 AC:3.287kW 2319 N FLOWER ST 949) 795-3472 2319 N Flower 05/17/22 Ex 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 44.1 oC). 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, 90 oC 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: SIGNSSEE 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 TENCO SOLAR - CSL#820684 18340 YORBA LINDA BLVD#107-497 YORBA LINDA,CA, 92886 949) 795-3472 SATKIN, PAUL 2319 N FLOWER ST DC:3.6 AC:3.287kW 2319 N Flower 05/17/22 2319 N Flower 05/17/22 2319 N Flower 05/17/22 2319 N Flower 05/17/22 2319 N Flower 05/17/22 2319 N Flower 05/17/22 13575 ELD RIDGE CT. CORONA, CA 92880 DOHERTY, MONICA Prepared For: TENCO SOLAR 18340 YORBA LINDA BLVD., #107-497 YORBA LINDA, CA 92886 (949) 795-3472 Design Criteria 1- Code: CALIFORNIA BLDG CODE 2019 / ASCE 7-16 2 - Wind: 95 MPH, Exposure: C 3 - Wood Species: DF-L No. 2 (SG = 0.5 ) Notice: Use restrictions of these calculations. The attached Calculations are valid only when bearing original signature hereon. Contractor/Client to verify existing dimensions/conditions prior to construction & solar racking is installed per manufacturer span requirements. The use of these calculations is solely intended for the above mentioned project. 1-844-PV ELITE | info@yoursolarplans.com 3000 E. Birch Street Suite 201 | Brea CA 92821 3/21/2022 Structural Calculations for SOLAR POWER SYSTEM CONNECTION CHECK AT: Job: 2319 N Flower 05/17/22 3/21/22, 9:19 AM ATC Hazards by Location https://hazards.atcouncil.org/#/wind?lat=33.7677294&lng=-117.8758072&address=2319 N Flower St%2C Santa Ana%2C CA 92706%2C USA 1/2 Hazards by Location Search Information Address: 2319 N Flower St, Santa Ana, CA 92706, USA Coordinates: 33.7677294, -117.8758072 Elevation: 132 ft Timestamp: 2022-03-21T16:17:37.192Z Hazard Type: Wind ASCE 7-16 MRI 10-Year 66 mph MRI 25-Year 71 mph MRI 50-Year 77 mph MRI 100-Year 81 mph Risk Category I 89 mph Risk Category II 95 mph Risk Category III 102 mph Risk Category IV 106 mph ASCE 7-10 MRI 10-Year 72 mph MRI 25-Year 79 mph MRI 50-Year 85 mph MRI 100-Year 91 mph Risk Category I 100 mph Risk Category II 110 mph Risk Category III-IV 115 mph ASCE 7-05 ASCE 7-05 Wind Speed 85 mph The results indicated here DO NOT reflect any state or local amendments to the values or any delineation lines made during the building code adoption process. Users should confirm any output obtained from this tool with the local Authority Having Jurisdiction before proceeding with design. Disclaimer Hazard loads are interpolated from data provided in ASCE 7 and rounded up to the nearest whole integer. Per ASCE 7, islands and coastal areas outside the last contour should use the last wind speed contour of the coastal area – in some cases, this website will extrapolate past the last wind speed contour and therefore, provide a wind speed that is slightly higher. NOTE: For queries near wind-borne debris region boundaries, the resulting determination is sensitive to rounding which may affect whether or not it is considered to be within a wind-borne debris region. Mountainous terrain, gorges, ocean promontories, and special wind regions shall be examined for unusual wind conditions. While the information presented on this website is believed to be correct, ATC and its sponsors and contributors assume no responsibility or liability for its accuracy. The material presented in the report should not be used or relied upon for any specific application without competent examination and verification of its accuracy, suitability and applicability by engineers or other licensed professionals. ATC does not intend that the use of this information replace the sound judgment of such competent professionals, having experience and knowledge in the field of practice, nor to substitute for the standard of care required of such professionals in interpreting and applying the results of the report provided by this website. Users of the information from this website assume all liability arising from such use. Use of the output of this website does not imply approval by the governing building code bodies responsible for building code approval and interpretation for the 132 ft Report a map errorMap data ©2022 Google, INEGI 2319 N Flower 05/17/22 ASCE 29.4.4 Rooftop Solar Panels Parallel to the Roof Surface on Buildings of All Heights and Roof Slopes. Roof Slope  = 18.4 ° Roof Shape Hip Tributary Width s = 6.00 ft Tributary Length l = 3.08 ft Effective Area A e = 10.28 ft2 Height of Structure h = 15 ft Wind Speed V = 95 mph Exposure Category C Building Width B = 30 ft Building Length L = 35 ft Zone Width a = 3 ft Elevation Height zg = 132 ft Wind Directionality Kd = 0.85 Topography Factor Kt = 1.00 Ground Elevation Factor Ke = 1.00 Velocity Pressure Exposure Coefficient Kz = 0.85 Velocity Pressure q z = 0.00256KzKztKdKeV 2 = 16.59 psf Solar Array Pressure Equalization a = 0.80 Array Edge Factor E = 1.50 Zone GCp p = qz(GCp)(E)(a) 3 2.60 -51.65 3r - - 3e - - 2 - - 2r 2.40 -47.64 2e 2.60 -51.65 2n - - 1 1.80 -35.78 1'- - 2319 N Flower 05/17/22 LAG SCREW ANALYSIS Loads Wind Pressures qz = -51.65 psf Solar Panel Load QD = 3 psf Panel Length l = 6.167 ft Panel Width b 3.425 ft Attachment Spacing s = 6 ft Portrait Tributary Area At = 18.50 ft2 Wind Load P W = qz * At = -956 lbs Dead Load P D = Q D * At = 55.5 lbs Uplift Pa = 0.6 P D + 0.6 Pw = -540 lbs Landscape Tributary Area At = b * s = 10.275 ft2 Wind Load P W = qz * At = -531 lbs Dead Load P D = Q D * At = 30.825 lbs Uplift Pa = 0.6 P D + 0.6 Pw = -300 lbs Lag Screw Specific Gravity of Lumber SG = 0.50 (Douglas Fir-Larch) Diameter of Lag Screw D = 5/16 in Withdraw Design /in 1800*SG 3/2 *D 3/4 = 266 lbs/in Depth of Embedment lp = 2.50 in Total Nominal Withdrawal Value W = W * l p = 665 lbs Load Duration Factor CD = 1.6 Withdrawal Design Value W' = W * C D = 1064 lbs Demand Capacity Ratio DCR = Pa / W' = 0.51 < 1 OK 2319 N Flower 05/17/22 ASCE 30.3.2 Design Wind Pressure Beam/ Top Chord Check Roof Slope  = 18.4 ° Roof Shape Hip Tributary Width s = 2.00 ft Tributary Length L = 15.00 ft Effective Area A = L ( MAX [ s , L/3] ) = 75 ft2 Height of Structure h = 15 ft Wind Speed V = 95 mph Exposure Category C Building Width B = 30 ft Building Length L = 35 ft Zone Width a = 3 ft Elevation Height zg = 132 ft Wind Directionality Kd = 0.85 Topography Factor Kt = 1.00 Ground Elevation Factor Ke = 1.00 Velocity Pressure Exposure Coefficient Kz = 0.85 Velocity Pressure q z = 0.00256KzKztKdKeV 2 = 16.59 psf Internal Pressure Coefficient (GCpi) = -0.18 Zone GCp p = q z [(GCp) - (Gcpi)] 3 2.19 -39.31 3r - - 3e - - 2 - - 2r 1.61 -29.62 2e 2.19 -39.31 2n - - 1 1.25 -23.73 1' - - 2319 N Flower 05/17/22 Beam/ Top Chord Check Lumber: Moment Demand # of Attachment per Rafter N A = Span : Orientation Lenght (ft) : Dead Load Roof Material:Q D = psf Live Load QLr = psf Wind Load p = psf Snow Load QS = psf Rafter Spacing s = in Wind Load, Portrait Portrait UL = Wind Load, Landscape Landscape U W = Linear Dead Load wd = plf Live Load wLr = plf Start ft Start ft End ft End ft Snow Load ws = plf Start ft Start ft End ft End ft Ma, Moment D lb-ft D+Lr lb-ft D+S lb-ft 0.6D+0.6W lb-ft D+0.45W+0.75Lr lb-ft D+0.45W+0.75S lb-ft Moment Capacity Framing Member Size Lumber Grade : DF-L No. 2 C M = 1 Ct = 1 Cr= CF = fb = psi Cfu =C i = Breadth b = in Depth d = in Section Modulus Sx = bd 2 / 6 = in3 Bending Stress Capacity Fb = C M * C t * Cr * C F * fb = psi Table 4.3.1 NDS 2015 Deflection Limit E = ksi I = in4 Transient Deflection in Transient Deflection Allowed > [OKAY] Total Deflection in Total Deflection Allowed > [OKAY] -39.31 DF-L No. 2 4 j lj (ft) pd,j (lbs) pw,j (lbs) ps,j (lbs) Landscape 1 5.9 30.8 -404 0.0 8.0 30.8 -404 -727 0.0 4 14.0 55.5 -727 0.0 0.0 7.00 7.00 0.00 0.00 1.00 Portrait 3 9.5 55.5 10.00 1 2 3 4 Eave 2 0.0 0.0 0.0 0.0 0.0 0 0.0 0.0 0.0 0.0 0 0.0 0.0 0.0 0.0 0 0.0 0.0 0 0.0 Portrait 0 0.0 0.0 0 0.0 20 40 0.0 0.0 0.0 0.0 0 0.0 Portrait 0 0.0 30.825 -404 0 0 0.0 0 5.25 0 0 0.0 Portrait 5.25 0.0 Portrait 0 0.0 0.0 AT (ft2) 18.5 10.275 pd (lbs) 55.5 -727 p w (lbs) ps (lbs) 0 14.84 2x4 1.15 1.5 15.00 14.84 15.00 900 1.50 3.50 182 230 182 476 302 302 DCR 0.9 1397 psi D 712 psi 0.51 3.06 1553 CD Fb' = C D * F b ASD Load Ma / S x 1.15 1785 psi D+S 712 psi 0.40 OKAY OKAY 1.25 1941 psi D+Lr 903 psi 0.47 OKAY 1.6 2484 psi 0.340 247 120 1600 5.36 0.6D+0.6W 1867 psi 0.75 OKAY 1.0 1 20 0.00 24 SHINGLE 0.277 303 180 1.6 2484 psi D+0.45W+0.75S 1185 psi 0.48 OKAY 1.6 2484 psi D+0.45W+0.75Lr 1185 psi 0.48 OKAY ൌ ሺ െ ሻ െ െ െ ‐600.0 ‐400.0 ‐200.0 0.0 200.0 400.0 600.0 0.000 2.000 4.000 6.000 8.000 10.000 12.000 14.000 16.000 2319 N Flower 05/17/22 EISMIC WEIGHT COMPARISON / ANALYSIS - (PER CEBC 2019 Part 10 Chapter 5 Section 502.5) PV System Weight Module Model HANWHA Panel Weight Wpanel = 48.5 lbs Number of Panels NPV = 9 Total PV System Weight W PV = Wpanel * NPV = 436.5 lbs Existing Roof Weight Roof Weight QD =10.0 psf Building Length Lbuild =35 ft Building Width W build =30 ft Roof Area Abuild =1050 ft2 Building Perimeter Pbuild = 130 ft Wall Height ht = 8 ft Wall weight Qwall = 15 psf Interior wall weight Qint = 10 psf Roof Load Wfloor = Abuild * QD = 10500 lbs Wall LoadWwall = ht /2 * Qwall * Pbuild + Abuild * Qint /2 = 13050 lbs Total Story Weight Wbuild = Wfloor + Wwall = 23550 lbs Percentage Weight Increase WPV / Wbuild = 1.85%< 10% OKAY 2319 N Flower 05/17/22 Rev: 7/15/2021 RESIDENTIAL PHOTOVOLTAIC CHECKLIST 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 2319 N Flower 05/17/22 2319 N Flower 05/17/22 2319 N Flower 05/17/22 The high-powered smart grid-ready Enphase IQ 7A Micro™ dramatically simpliﬁes the installation process while achieving the highest system efﬁciency for systems with 60-cell and 72-cell modules. Part of the Enphase IQ System, the IQ 7A Micro integrates with the Enphase IQ Envoy™, Enphase IQ Battery™, and the Enphase Enlighten™ monitoring and analysis software. The IQ Series Microinverters extend the reliability standards set forth by previous generations and undergo over a million hours of power-on testing, enabling Enphase to provide an industry-leading warranty of up to 25 years. Enphase IQ 7A Microinverter To learn more about Enphase offerings, visit enphase.com Data Sheet Enphase Microinverters Region: AMERICAS High Power • Peak output power 366 VA @ 240 VAC and 295 VA @ 208 VAC Easy to Install • Lightweight and simple • Faster installation with improved, lighter two-wire cabling • Built-in rapid shutdown compliant (NEC 2014, 2017 & 2020) Efﬁcient and Reliable • Optimized for high powered 60-cell and 72-cell modules • Highest CEC efﬁciency of 97% • More than a million hours of testing • Class II double-insulated enclosure • UL listed Smart Grid Ready • Complies with advanced grid support, voltage and frequency ride- through requirements • Envoy and Internet connection required • Conﬁgurable for varying grid proﬁles • Meets CA Rule 21 (UL 1741-SA) 2319 N Flower 05/17/22 1. No enforced DC/AC ratio. See the compatibility calculator at https://enphase.com/en-us/support/module-compatibility. 2. CEC peak power tracking voltage range is 38 V to 43 V. 3. Maximum continuous input DC current is 10.2A. 4. 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. To learn more about Enphase offerings, visit enphase.com © 2021 Enphase Energy. All rights reserved. Enphase, the Enphase logo, Enphase IQ 7A, Enphase IQ Battery, Enphase Enlighten, Enphase IQ Envoy, and other trademarks or service names are the trademarks of Enphase Energy, Inc. Data subject to change. 11-04-2021 INPUT (DC) IQ7A-72-2-US Commonly used module pairings¹ 295 W–460 W + Module compatibility 60-cell, 66-cell and 72-cell PV modules Maximum input DC voltage 58 V Power point tracking voltage range² 18 V–58 V Min/Max start voltage 33 V / 58 V Max DC short circuit current (module Isc)³ 15 A Overvoltage class DC port II DC port backfeed current 0 A PV array conﬁguration 1 x 1 ungrounded array; No additional DC side protection required; AC side protection requires max 20A per branch circuit OUTPUT (AC) @ 240 VAC @ 208 VAC Peak output power 366 VA 295 VA Maximum continuous output power 349 VA 290 VA Nominal (L-L) voltage/range4 240 V / 211–264 V 208 V / 183–229 V Maximum continuous output current 1.45 A (240 VAC) 1.39 A (208 VAC) Nominal frequency 60 Hz Extended frequency range 47–68 Hz AC short circuit fault current over 3 cycles 5.8 Arms Maximum units per 20 A (L-L) branch circuit5 11 (240 VAC)11 (208 VAC) Overvoltage class AC port III AC port backfeed current 18 mA Power factor setting 1.0 Power factor (adjustable) 0.85 leading ... 0.85 lagging EFFICIENCY @240 VAC @208 VAC CEC weighted efﬁciency 97.0 % 96.5% MECHANICAL Ambient temperature range -40ºC to +60ºC Relative humidity range 4% to 100% (condensing) Connector type: DC (IQ7A-72-2-US) MC4 Dimensions (HxWxD) 212 mm x 175 mm x 30.2 mm (without bracket) 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 Environmental category / UV exposure rating NEMA Type 6 / outdoor FEATURES Communication Power Line Communication (PLC) Monitoring Enlighten Manager and MyEnlighten monitoring options Compatible with Enphase IQ Envoy Disconnecting means The AC and DC connectors have been evaluated and approved by UL for use as the load-break disconnect required by NEC 690. Compliance 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 C22.1-2015 Rule 64-218 Rapid Shutdown of PV Systems, for AC and DC conductors, when installed according manufacturer’s instructions. Enphase IQ 7A Microinverter 2319 N Flower 05/17/22 The Enphase IQ Combiner 3™ with Enphase IQ Envoy™ consolidates interconnection equipment into a single enclosure and streamlines PV and storage installations by providing a consistent, pre-wired solution for residential applications. It offers up to four 2-pole input circuits and Eaton BR series busbar assembly. Enphase IQ Combiner 3 (X-IQ-AM1-240-3) To learn more about Enphase offerings, visit enphase.com Data Sheet Enphase Networking Smart • Includes IQ Envoy for communication and control • Flexible networking supports Wi-Fi, Ethernet, or cellular • Optional AC receptacle available for PLC bridge • Provides production metering and optional consumption monitoring Simple • Reduced size from previous combiner • Centered mounting brackets support single stud mounting • Supports back and side conduit entry • Up to four 2-pole branch circuits for 240 VAC plug-in breakers (not included) • 80 A total PV or storage branch circuits Reliable • Durable NRTL-certiﬁed NEMA type 3R enclosure • Five-year limited warranty • UL listed 2319 N Flower 05/17/22 2319 N Flower 05/17/22 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. 2319 N Flower 05/17/22 TECHNICAL BRIEF © 2015 Enphase Energy Inc. All rights reserved. January 20151 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 oth er 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. 2319 N Flower 05/17/22 NEC 2014 Enphase System Code Compliance © 2015 Enphase Energy Inc. All rights reserved. January 20152 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 2319 N Flower 05/17/22 NEC 2014 Enphase System Code Compliance © 2015 Enphase Energy Inc. All rights reserved. January 20153 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. 2319 N Flower 05/17/22 NEC 2014 Enphase System Code Compliance © 2015 Enphase Energy Inc. All rights reserved. January 20154 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. 2319 N Flower 05/17/22 2319 N Flower 05/17/22 2319 N Flower 05/17/22 2319 N Flower 05/17/22 2319 N Flower 05/17/22 2319 N Flower 05/17/22 2319 N Flower 05/17/22 2319 N Flower 05/17/22 2319 N Flower 05/17/22 2319 N Flower 05/17/22 2319 N Flower 05/17/22 2319 N Flower 05/17/22 2319 N Flower 05/17/22 2319 N Flower 05/17/22 2319 N Flower 05/17/22 2319 N Flower 05/17/22 2319 N Flower 05/17/22 2319 N Flower 05/17/22 2319 N Flower 05/17/22 2319 N Flower 05/17/22 THE COMPLETE ROOF ATTACHMENT SOLUTION FEATURING TECHNOLOGY FLASHKIT PRO is the complete attachment solution for composition shingle roofs. Featuring Unirac’s patented SHED & SEAL technology, a weather proof system which provides the ultimate protection against roof leaks. Kitted in 10 packs for maximum convenience, ﬂashings and hardware are available in Mill or Dark ﬁnishes. With FLASHKIT pro, you have everything you need for a quick, professional installation. YOUR COMPLETE SOLUTION Flashings, lags, continuous slot L-Feet and hardware CONVENIENT 10 PACKS Packaged for speed and ease of handling FLASHKIT PRO 25 YEAR FULL-SYSTEM WARRANTY TRUSTED WATER SEAL FLASHINGS FOR QUESTIONS OR CUSTOMER SERVICE VISIT UNIRAC.COM OR CALL (505) 248-2702 2319 N Flower 05/17/22 FASTER INSTALLATION. 25-YEAR WARRANTY. FLASH KIT PRO IS THE COMPLETE FLASHING AND ATTACHMENT SOLUTION FOR COMPOSITION ROOFS. FOR QUESTIONS OR CUSTOMER SERVICE VISIT UNIRAC.COM OR CALL (505) 248-2702 PRE-INSTALL • Locate roof rafters and snap chalk lines to mark the installation point for each roof attachment. • Drill a 7/32” pilot hole at each roof attachment. Fill each pilot hole with sealant. STEP 1 INSTALL FLASHKIT PRO FLASHING • Add a U-shaped bead of roof sealant to the underside of the ﬂashing with the open side of the U pointing down the roof slope. Slide the aluminum ﬂashing underneath the row of shingles directly up slope from the pilot hole as shown. Align the indicator marks on the lower end of the ﬂashing with the chalk lines on the roof to center the raised hole in the ﬂashing over the pilot hole in the roof. When installed correctly, the ﬂashing will extend under the two courses of shingles above the pilot hole. STEP 2 INSTALL L-FOOT • Fasten L-foot and Flashing into place by passing the included lag bolt and pre-installed stainless steel-backed EPDM washer through the L-foot EPDM grommet, and the raised hole in the ﬂashing, into the pilot hole in the roof rafter. • Drive the lag bolt down until the L-foot is held ﬁrmly in place. It is normal for the EPDM on the underside of the stainless steel backed EPDM washer to compress and expand beyond the outside edge of the steel washer when the proper torque is applied. TIP: • Use caution to avoid over-torqueing the lag bolt if using an impact driver. • Repeat Steps 1 and 2 at each roof attachment point. STEP 3 ATTACH L-FOOT TO RAIL • Insert the included 3/8"-16 T-bolts into the lower slot on the Rail (sold separately), spacing the bolts to match the spacing between the roof attachments. • Position the Rail against the L-Foot and insert the threaded end of the T-Bolt through the continuous slot in the L-Foot. Apply anti-seize to bolt threads to prevent galling of the T-bolt and included 3/8” serrated ﬂange nut. Place the 3/8” ﬂange nut on the T-bolt and ﬁnger tighten. Repeat STEP 3 until all L-Feet are secured to the Rail with a T-bolt. Adjust the level and height of the Rail and torque each bolt to 30ft-lbs. INSTALL FLASHKIT PRO FLASHING STEP 1 STEP 2 STEP 3 INSTALL L-FOOT ATTACH L-FOOT TO RAIL FLASHKIT PRO INSTALLATION GUIDE 2319 N Flower 05/17/22