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LA185876 - 20975 Goodhue Way 11.4.20
Wyssling Consulting 76 North Meadowbrook Drive Alpine, UT 84004 Scott E. Wyssling, PE, PP, CME office (201) 874-3483 swyssling@wysslingconsulting.com November 3, 2020 Everlight Solar Construction PO Box 930550 Verona, WI 53593 Re: Engineering Services McConnell Residence 20975 Goodhue Way, Lakeville, MN 3.836 kW System To Whom It May Concern: Pursuant to your request, we have reviewed the following information regarding solar panel installation on the roof of the above referenced home: 1. Site Visit/Verification Form prepared by an Everlight Solar representative identifying specific site information including size and spacing of rafters for the existing roof structure. 2. Design drawings of the proposed system including a site plan, roof plan and connection details for the solar panels. This information was prepared by Everlight Solar and will be utilized for approval and construction of the proposed system. 3. Photographs of the interior and exterior of the roof system identifying existing structural members and their conditions. Based on the above information we have evaluated the structural capacity of the existing roof system to support the additional loads imposed by the solar panels and have the following comments related to our review and evaluation: Description of Residence: The existing residence is typical wood framing construction with the roof system consisting of truss system with all chords constructed of 2 x 4 dimensional lumber at 24” on center. The attic space is unfinished and photos indicate that there was free access to visually inspect the size and condition of the roof rafters. All wood material utilized for the roof system is assumed to be Doug-Fir #2 or better with standard construction components. The existing roofing material consists of composite asphalt shingles. Photos of the dwelling also indicate that there is a permanent foundation. A. Loading Criteria Used • 115 MPH wind loading based on ASCE 7-16 Exposure Category “C” at a slope of 30 degrees • 7 PSF = Dead Load roofing/framing Live Load = 20 PSF Snow Load = 50 PSF • 3 PSF = Dead Load solar panels/mounting hardware Total Dead Load =10 PSF The above values are within acceptable limits of recognized industry standards for similar structures in accordance with the Minnesota Residential Code (2018 IRC). Analysis performed of the existing roof structure utilizing the above loading criteria indicates that the existing rafters will support the additional panel loading without damage, if installed correctly. Page 2 of 2 B. Solar Panel Anchorage 1. The solar panels shall be mounted in accordance with the most recent “IronRidge Solar Installation Manual”, which can be found on the IronRidge Solar website (http://ironridgesolar.com/). If during solar panel installation, the roof framing members appear unstable or deflect non-uniformly, our office should be notified before proceeding with the installation. 2. Maximum allowable pullout per lag screw is 235 lbs/inch of penetration as identified in the National Design Standards (NDS) of timber construction specifications for Doug-Fir (North Lumber) assumed. Based on our evaluation, the pullout value, utilizing a penetration depth of 2 ½”, is less than what is allowable per connection and therefore is adequate. Based on the variable factors for the existing roof framing and installation tolerances, using a thread depth of 2 ½” with a minimum size of 5/16” lag screw per attachment point for panel anchor mounts should be adequate with a sufficient factor of safety. 3. Considering the roof slopes, the size, spacing, condition of roof, the panel supports shall be placed no greater than 48” o/c. 4. Panel supports connections shall be staggered to distribute load to adjacent trusses. Based on the above evaluation, it is the opinion of this office that with appropriate panel anchors being utilized the roof system will adequately support the additional loading imposed by the solar panels. This evaluation is in conformance with the Minnesota Residential Code (2018 IRC), current industry standards, and is based on information supplied to us at the time of this report. Should you have any questions regarding the above or if you require further information do not hesitate to contact me. Very truly yours, Scott E. Wyssling, PE Minnesota License No. 57927 SITE INFORMATION: Thomas Mcconnell 20975 Goodhue Way, Lakeville, MN 55044 MAX CONTINUOUS AC SYSTEM SIZE: 3.836 kW AC DC SYSTEM SIZE: 4.48 kW DC Lat, Long: 44.6454603 , -93.2203368(14) Silfab SIL-320 NL PV MODULES(7) AP Systems YC600 INVERTERSCONTRACTOR INFORMATION:Everlight Solar ConstructionPO Box 930550Verona, WI 53593License# DCQ-111802116833.786.4387 ext. 701Xcel Energy MNPV01 COVER PAGE PV02 PROPERTY PLAN PV03 ROOF PLAN PV04 ROOF ATTACHMENTS + BOM PV05 MOUNTING DETAIL PV06 ELECTRICAL DIAGRAM PV07 LABELS PV08 PLACARD PV09 SITE PHOTOS DATE: November 2, 2020 PV01 PAGE: SHEET NAME: COVER PAGE DRAWN BY: SoloCAD GENERAL NOTES: 1.INSTALLATION OF SOLAR PHOTOVOLTAIC SYSTEM SHALL BE IN ACCORDANCE WITH NEC ARTICLE 690, AND ALL OTHER APPLICABLE NEC CODES WHERE NOTED OR EXISTING. 2.PROPER ACCESS AND WORKING CLEARANCE AROUND EXISTING AND PROPOSED ELECTRICAL EQUIPMENT WILL COMPLY WITH NEC ARTICLE 110. 3.ALL WIRES, INCLUDING THE GROUNDING ELECTRODE CONDUCTOR SHALL BE PROTECTED FROM PHYSICAL DAMAGE IN ACCORDANCE WITH NEC ARTICLE 250 4.THE PV MODULES ARE CONSIDERED NON-COMBUSTIBLE; THIS SYSTEM IS UTILITY INTERACTIVE PER UL 1741 AND DOES NOT INCLUDE STORAGE BATTERIES OR OTHER ALTERNATIVE STORAGE SOURCES. 5.ALL DC WIRES SHALL BE SIZED ACCORDING TO [NEC 690.8] 6.DC CONDUCTORS SHALL BE WITHIN PROTECTED RACEWAYS IN ACCORDANCE WITH [NEC 690.31] 7.ALL SIGNAGE TO BE PLACED IN ACCORDANCE WITH LOCAL JURISDICTIONAL BUILDING CODE. APPLICABLE GOVERNING CODES: DESCRIPTION OF DESIGN: INSTALLATION OF GRID -TIED, UTILITY INTERACTIVE PHOTOVOLTAIC SYSTEM AERIAL VIEW:MAP VIEW:SHEET INDEX: EQUIPMENT: MAX CONTINUOUS AC SYSTEM SIZE: 3.836 kW AC DC SYSTEM SIZE: 4.48 kW DC (14) Silfab SIL-320 NL PV MODULES (7) AP Systems YC600 INVERTERS RACKING: SolarRoofHook - 48" O.C. SITE SPECIFICATIONS: OCCUPANCY: R-3 ZONING: RESIDENTIAL 2020 NEC 2020 MRC 2020 MFC 2020 MBC SITE INFORMATION: Thomas Mcconnell 20975 Goodhue Way, Lakeville, MN 55044 MAX CONTINUOUS AC SYSTEM SIZE: 3.836 kW AC DC SYSTEM SIZE: 4.48 kW DC Lat, Long: 44.6454603 , -93.2203368(14) Silfab SIL-320 NL PV MODULES(7) AP Systems YC600 INVERTERSJB M MSP AC PV CCONTRACTOR INFORMATION:Everlight Solar ConstructionPO Box 930550Verona, WI 53593License# DCQ-111802116833.786.4387 ext. 701Xcel Energy MNDATE: November 2, 2020 PV02 PAGE: SHEET NAME: PROPERTY PLAN DRAWN BY: SoloCAD SCALE: EQUIPMENT LEGEND: INVERTER VISIBLE, LOCKABLE, LABELED AC DISCONNECT METER SOCKET (FOR UTILITY PV METER) UTILITY METER MAIN SERVICE PANEL LC LOAD CENTER FIRE ACCESS PATHWAY (3' TYP) C INV PV AC MSP M COMBINER BOX PROPERTY LINE FRONT OF HOME 20975 Goodhue Way MP1 PITCH: 30° AZIMUTH: 180° BATT BATTERY(IES) VISIBLE, LOCKABLE, LABELED AC DISCONNECT LOCATED WITHIN 10' OF UTILITY METER1" = 19.13' SOLAR ARRAY INVERTERS BEHIND PANELS 2' BETWEEN PROD METER AND METER 2' BETWEEN PROD METER AND AC DISCONNECT 2' BETWEEN COMBINER BOX AND AC DISCONNECT 24/7 UNESCORTED KEYLESS ACCESS SHALL BE PROVIDED TO XCEL ENERGY FOR ALL XCEL ENERGY OWNED METERS AND DISCONNECTS. CASE #: 04041202 ELECTRIC SERVICE LINES ARE UNDERGROUND NOT OVERHEAD 140'-1" 65'-0" NO CLEARANCE ISSUES AROUND HOME OR SOLAR ARRAY GLADE AVE (200 FT.) SITE INFORMATION: Thomas Mcconnell 20975 Goodhue Way, Lakeville, MN 55044 MAX CONTINUOUS AC SYSTEM SIZE: 3.836 kW AC DC SYSTEM SIZE: 4.48 kW DC Lat, Long: 44.6454603 , -93.2203368(14) Silfab SIL-320 NL PV MODULES(7) AP Systems YC600 INVERTERSJB M MSP AC PV CCONTRACTOR INFORMATION:Everlight Solar ConstructionPO Box 930550Verona, WI 53593License# DCQ-111802116833.786.4387 ext. 701Xcel Energy MNDATE: November 2, 2020 PV03 PAGE: SHEET NAME: ROOF PLAN DRAWN BY: SoloCAD EQUIPMENT LEGEND: INVERTER VISIBLE, LOCKABLE, LABELED AC DISCONNECT METER SOCKET (FOR UTILITY PV METER) UTILITY METER MAIN SERVICE PANEL LC LOAD CENTER FIRE ACCESS PATHWAY (3' TYP) C INV PV AC MSP M COMBINER BOX FRONT OF HOME MP1 PITCH: 30° AZIMUTH: 180° BATT BATTERY(IES) VISIBLE, LOCKABLE, LABELED AC DISCONNECT LOCATED WITHIN 10' OF UTILITY METER 18" TYP JB SITE INFORMATION: Thomas Mcconnell 20975 Goodhue Way, Lakeville, MN 55044 MAX CONTINUOUS AC SYSTEM SIZE: 3.836 kW AC DC SYSTEM SIZE: 4.48 kW DC Lat, Long: 44.6454603 , -93.2203368(14) Silfab SIL-320 NL PV MODULES(7) AP Systems YC600 INVERTERSCONTRACTOR INFORMATION:Everlight Solar ConstructionPO Box 930550Verona, WI 53593License# DCQ-111802116833.786.4387 ext. 701EQUIPMENT INFORMATION: RAIL MANUFACTURER IronRidge RAIL PART NUMBER XR-100 ATTACHMENTS Quickbolt ATTACHMENT QTY 24 MIDCLAMP QTY 24 ENDCLAMP QTY 8 SPLICE QTY 4 ROOF INFO: ROOF TYPE asphalt_shingle ROOF FRAMING manufactured_truss RAFTER/TOP CHORD SIZE 2x4 RAFTER/TOP CHORD SPACING 24 ATTACHMENT SPACING 48Xcel Energy MNDATE: November 2, 2020 PV04 PAGE: SHEET NAME: ROOF ATTACHMENTS + BOM DRAWN BY: SoloCAD ROOF ATTACHMENT COUNT:24 PV MODULE COUNT:14 ARRAY AREA:MODULE COUNT * 18.06ft² = 252.84 ROOF AREA:2355 ft² PERCENT OF ROOF COVERED:11% ARRAY WEIGHT:MODULE COUNT * 50lbs = 700 DISTRIBUTED LOAD:ARRAY LBS/ATTACHMENTS = 29.17 POINT LOAD: (lbs/ft²)(ARRAY) WEIGHT/AREA = 2.77 lbs/ft² PHOTOVOLTAIC ARRAY STRUCTURAL CRITERIA: RAIL L-FOOT/ATTACHMENT BRACKET (E) ROOF FRAMING 5/16" STAINLESS STEEL LAG-BOLT WITH 2-1/2" MIN. EMBEDMENT AND FLAT WASHER FLASHING PV MODULE (E) COMP SHINGLE ROOF (1 LAYER) RAIL END CLAMP PV MODULE MID CLAMP PV MODULE 4" 2 1 2" MIN. DEPTH RAIL RAIL FLASHING & LAG-BOLT 2'-8" MIN - 3'-10" MAX 3 RAIL PV MODULE " MAX."1'-8" MAX. 21 FRONT VIEW 10" MIN - 1'-4" MAX2'-8" MIN - 3'-10" MAX 10" MIN - 1'-4" MAX SIDE VIEW (E) RAFTER/TOP CHORDS (E) RAFTER/TOP CHORD DETAIL, MOUNTING AND FLASHING END CLAMP DETAILS MID CLAMP DETAILS 3 21 SITE INFORMATION: Thomas Mcconnell 20975 Goodhue Way, Lakeville, MN 55044 MAX CONTINUOUS AC SYSTEM SIZE: 3.836 kW AC DC SYSTEM SIZE: 4.48 kW DC Lat, Long: 44.6454603 , -93.2203368(14) Silfab SIL-320 NL PV MODULES(7) AP Systems YC600 INVERTERSCONTRACTOR INFORMATION:Everlight Solar ConstructionPO Box 930550Verona, WI 53593License# DCQ-111802116833.786.4387 ext. 701EQUIPMENT INFORMATION: RAIL MANUFACTURER IronRidge RAIL PART NUMBER XR-100 ATTACHMENTS Quickbolt ATTACHMENT QTY 24 MIDCLAMP QTY 24 ENDCLAMP QTY 8 SPLICE QTY 4 ROOF INFO: ROOF TYPE asphalt_shingle ROOF FRAMING manufactured_truss RAFTER/TOP CHORD SIZE 2x4 RAFTER/TOP CHORD SPACING 24 ATTACHMENT SPACING 48Xcel Energy MNDATE: November 2, 2020 PV05 PAGE: SHEET NAME: MOUNTING DETAIL DRAWN BY: SoloCAD ROOF ATTACHMENT COUNT:24 PV MODULE COUNT:14 ARRAY AREA:MODULE COUNT * 18.06ft² = 252.84 ROOF AREA:2355 ft² PERCENT OF ROOF COVERED:11% ARRAY WEIGHT:MODULE COUNT * 50lbs = 700 DISTRIBUTED LOAD:ARRAY LBS/ATTACHMENTS = 29.17 POINT LOAD: (lbs/ft²)(ARRAY) WEIGHT/AREA = 2.77 lbs/ft² PHOTOVOLTAIC ARRAY STRUCTURAL CRITERIA: 4 4 (N) FUSES UTILITY PV PRODUCTION METER BASE PV AC DISCONNECT FUSED, AIC 10kA VISIBLE, LOCKABLE, LABELED, OPEN, 240V, 2-POLE (PV OCPD) 4 (E) LOADS N G SUPPLY SIDE CONNECTION: NEC 230.46, NEC 230.79, NEC 705.12(A) LUG KIT TO BE ADDED (E)GROUNDING ELECTRODE INTERCONNECTION NOTES 1. GROUND FAULT PROTECTION IN ACCORDANCE WITH [NEC 215.9] & [NEC 230.95] 2. SUPPLY SIDE INTERCONNECTION ACCORDING TO [NEC705.12(A)] WITH SERVICE ENTRANCE CONDUCTORS IN ACCORDANCE WITH [NEC 240.21(B)] DISCONNECT NOTES 1. DISCONNECTING SWITCHES SHALL BE WIRED SUCH THAT WHEN THE SWITCH IS OPENED THE CONDUCTORS REMAINING LIVE ARE CONNECTED TO THE TERMINALS MARKED “LINE SIDE” (TYPICALLY THE UPPER TERMINALS) 2. AC DISCONNECT MUST BE ACCESSIBLE TO QUALIFIED UTILITY PERSONNEL, BE LOCKABLE, AND BE A VISIBLE-BREAK SWITCH. 3. FUSED AC DISCONNECT TO BE USED. (E) MAIN SERVICE PANEL (E) MAIN BREAKER (E) 120/240 VAC TO UTILITY GRID (E)UTILITY METER STRING [1] N G AC COMBINER BOX SOLAR LOADS ONLY UL 1741 COMPLIANT AC DC AC DC J-BOX (N) 100A (1) 20A-2P J-BOX 1 2 3 SITE INFORMATION: Thomas Mcconnell 20975 Goodhue Way, Lakeville, MN 55044 MAX CONTINUOUS AC SYSTEM SIZE: 3.836 kW AC DC SYSTEM SIZE: 4.48 kW DC Lat, Long: 44.6454603 , -93.2203368(14) Silfab SIL-320 NL PV MODULES(7) AP Systems YC600 INVERTERSCONTRACTOR INFORMATION:Everlight Solar ConstructionPO Box 930550Verona, WI 53593License# DCQ-111802116833.786.4387 ext. 7011 2 3 4(1) 12-2 TC-ER, THWN-2, COPPER (OR CODE APPROVED EQUIVALENT) (1) 6 AWG BARE, COPPER (GROUND) (1) 10 AWG THWN-2, or THHN, or 10/2 NM-B COPPER - (POSITIVE) (1) 10 AWG THWN-2, or THHN, or 10/2 NM-B COPPER - (NEGATIVE) (1) 10 AWG THWN-2, or THHN, or 10/2 NM-B COPPER - (GROUND) (1) 3/4" LIQUID TIGHT OR EMT OR FMC (OR CODE APPROVED EQUIVALENT) (1) 10 AWG THHN/THWN-2, COPPER - (L1) (1) 10 AWG THHN/THWN-2 COPPER - (L2) (1) 10 AWG THHN/THWN-2 (GROUND) CONDUIT: 3/4" LIQUID TIGHT OR EMT (OR CODE APPROVED EQUIVALENT) (1) 6 AWG THWN-2 COPPER - (L1) (1) 6 AWG THWN-2 COPPER - (L2) (1) 6 AWG THWN-2 COPPER - (NEUTRAL) (1) 10 AWG THWN-2 COPPER - (GROUND) (1) CONDUIT: 3/4" LIQUID TIGHT OR EMT (OR CODE APPROVED EQUIVALENT) SERVICE EQUIPMENT & PV OCPD RATINGS MAIN BREAKER RATING 200A MAIN SERVICE BUS RATING 200A PV OCPD RATING 20A AC VOLTAGE 240V AC DISCONNECT RATING 60A STRINGS: STRING 1 14 PV MODULES Xcel Energy MNDATE: November 2, 2020 PV06 PAGE: SHEET NAME: ELECTRICAL DIAGRAM DRAWN BY: SoloCAD WIRE SCHEDULE EQUIPMENT SCHEDULE: TYPE:QTY:DESCRIPTION:RATING: MODULES:(14)Silfab SIL-320 NL 320 W INVERTERS:(7)AP Systems YC600 548 W AC DISCONNECT(S):(1)PV AC DISCONNECT, 240V, 2-POLE 60 A GROUNDING & GENERAL NOTES: 1. A SECOND FACILITY GROUNDING ELECTRODE IS NOT REQUIRED PER [NEC 690.47(C)(3)] 2. PV INVERTER IS UNGROUNDED, TRANSFORMER-LESS TYPE. 3. DC GEC AND AC EGC TO REMAIN UNSPLICED, OR SPLICED TO EXISTING ELECTRODE 4. ANY EXISTING WIRING INVOLVED WITH PV SYSTEM CONNECTION THAT IS FOUND TO BE INADEQUATE PER CODE SHALL BE CORRECTED PRIOR TO FINAL INSPECTION. 5. JUNCTION BOX QUANTITIES, AND PLACEMENT SUBJECT TO CHANGE IN THE FIELD - JUNCTION BOXES DEPICTED ON ELECTRICAL DIAGRAM REPRESENT WIRE TYPE TRANSITIONS. 6. AC DISCONNECT NOTED IN EQUIPMENT SCHEDULE OPTIONAL IF OTHER AC DISCONNECTING MEANS IS LOCATED WITHIN 10' OF SERVICE DISCONNECT. CASE #: 04041202 DESIGN SHALL MEET NEC REQUIREMENTS PHOTOVOLTAIC UTILITY AC DISCONNECT 1-PH, 3-WIRE 120/240V 200 AMP REFERENCE POINT OF APPLICABILITY NO LOADS OR STAGE SYSTEM ON DER SIDE OF PRODUCTION METER THE PV PRODUCTION METER SOCKET MUST HAVE LEVER BYPASS/BYPASS CUSTOMER OWNED PV PRODUCTION METER MAXIMUM INPUT VOLTAGE 55V MAXIMUM INPUT CURRENT 12A x2 NOMINAL OUTPUT VOLTAGE 240V NOMINAL OUTPUT CURRENT 2.28A 1-PHASE 60HZ AP SYSTEMS YC600 (240V) SPECS 2'2'VARIES LOAD SIDELINE SIDE MSP LOCATED IN BASEMENT INTERCONNECTION TYPE IS SECONDARY SITE INFORMATION: Thomas Mcconnell 20975 Goodhue Way, Lakeville, MN 55044 MAX CONTINUOUS AC SYSTEM SIZE: 3.836 kW AC DC SYSTEM SIZE: 4.48 kW DC Lat, Long: 44.6454603 , -93.2203368(14) Silfab SIL-320 NL PV MODULES(7) AP Systems YC600 INVERTERSCONTRACTOR INFORMATION:Everlight Solar ConstructionPO Box 930550Verona, WI 53593License# DCQ-111802116833.786.4387 ext. 701LABEL VALUES: DESCRIPTION VALUE: DC IMP:9.74 DC VMP:32.88 DC VOC:40.1 DC ISC:SEE DATASHEET DC SYSTEM SIZE (W):4480 AC OPERATING CURRENT:SEE DATASHEET AC VOLTAGE:240Xcel Energy MNDATE: November 2, 2020 PV07 PAGE: SHEET NAME: LABELS DRAWN BY: SoloCAD LABEL 3 AT POINT OF INTERCONNECTION, MARKED AT AC DISCONNECTING MEANS. [NEC 690.54, NEC 690.13 (B)] LABEL 4 AT POINT OF INTERCONNECTION FOR EQUIPMENT CONTAINING OVERCURRENT DEVICES IN CIRCUTS SUPPLYING POWER TO A BUSBAR OR CONDUCTOR SUPPLIED FORM MULTIPLE SOURCES, EACH SERVICE EQUIPMENT AND ALL ELECTRIC POWER PRODUCTION SOURCE LOCATIONS. [NEC 705.12(B)(3)] LABEL 5 PLACED ADJACENT TO THE BACK-FED BREAKER FROM THE INVERTER IF TIE IN CONSISTS OF LOAD SIDE CONNECTION TO BUSBAR. [NEC 705.12(D)(2)(3)(b)] *ELECTRICAL DIAGRAM SHOWN ABOVE IS FOR LABELING PURPOSES ONLY. NOT AN ACTUAL REPRESENATION OF EQUIPMENT AND CONNECTIONS TO BE INSTALLED. LABEL LOCATIONS PRESENTED MAY VERY DEPENDING ON TYPE OF INTERCONNECTION METHOD AND LOCATION PRESENTED ON PV5 OF 3 LINE DIAGRAM. PV5 LINE DIAGRAM TO REFLECT ACTUAL REPRESENTATION OF PROPOSED SCOPE OF WORK. JUNCTION BOX OR COMBINER BOX MAIN SERVICE PANEL AC DISCONNECT EXISTING SUB PANEL (IF WHERE POINT OF INTERCONNECTION IS MADE) PV COMBINER SUBPANEL - IF USED TO COMBINE PV OUTPUT CIRCUITS AC DC INVERTER (S) INTEGRATED DC DISCONNECT 2 3 47 3 9 5 (ONLY IF PV INTERCONNECTION CONSISTS OF LOAD SIDE BREAKER) 6 10 1 1 1 1 4 5 (ONLY IF PV INTERCONNECTION CONSISTS OF LOAD SIDE BREAKER) 4 6 3 LABELING DIAGRAM: 12 11 8OR LABEL 6 AT DIRECT-CURRENT EXPOSED RACEWAYS, CABLE TRAYS, COVERS AND ENCLOSURES OF JUNCTION BOXES, AND OTHER WIRING METHODS; SPACED AT MAXIMUM 10FT SECTION OR WHERE SEPARATED BY ENCLOSURES, WALLS, PARTITIONS, CEILINGS, OR FLOORS. [NEC 690.31(G)(3&4)] LABEL 10 (ONLY IF 3 OR MORE SUPPLY SOURCES TO A BUSBAR) SIGN LOCATED AT LOAD CENTER IF IT CONTAINS 3 OR MORE POWER SOURCES. [NEC 705.12(D)(2)(3)(C)] LABEL 9 SIGN LOCATED AT RAPID SHUT DOWN DISCONNECT SWITCH [NEC 690.56(C)(3)]. LABEL 7 FOR PV SYSTEMS THAT SHUT DOWN THE ARRAY AND CONDUCTORS LEAVING THE ARRAY: SIGN TO BE LOCATED ON OR NO MORE THAN 3 FT AWAY FROM SERVICE DISCONNECTING MEANS TO WHICH THE PV SYSTEMS ARE CONNECTED AND SHALL INDICATE THE LOCATION OF ALL IDENTIFIED RAPID SHUTDOWN SWITCHES IF NOT AT THE SAME LOCATION. [NEC 690.56(C)(1)(A)] LABEL 8 FOR PV SYSTEMS THAT ONLY SHUT DOWN CONDUCTORS LEAVING THE ARRAY: SIGN TO BE LOCATED ON OR NO MORE THAN 3 FT AWAY FROM SERVICE DISCONNECTING MEANS TO WHICH THE PV SYSTEMS ARE CONNECTED AND SHALL INDICATE THE LOCATION OF ALL IDENTIFIED RAPID SHUTDOWN SWITCHES IF NOT AT THE SAME LOCATION. [NEC 690.56(C)(1)(B)] LABEL 11 PLACARD TO BE PLACED AT THE MAIN BILLING METER PER XCEL ENERGY. LABEL 1 FOR PV DISCONNECTING MEANS WHERE ALL TERMINALS OF THE DISCONNECTING MEANS MAY BE ENERGIZED IN THE OPEN POSITION. [NEC 690.13(B), NEC 705.22] LABEL 2 AT EACH DC DISCONNECTING MEANS, INCLUDING THE DC DISCONNECT AT THE INVERTER. [NEC 690.53, NEC 690.13(B)] LABEL 13 SIGN LOCATED AT MAIN SERVICE DISCONNECTING MEANS IF ALL ELECTRICAL POWER SOURCE DISCONNECTING MEANS ARE GROUPED WITHIN 10' AND LINE OF SITE OF MAIN SERVICE DISCONNECT [NEC 690.56(B) & NEC 705.10]. LABEL 14 SIGN LOCATED AT AC COMBINER BOX FOR ALL MICRO-INVERTER / AC MODULE INSTALLS (IF APPLICABLE). 13 14 LABELING NOTES: 1.LABELS CALLED OUT ACCORDING TO ALL COMMON CONFIGURATIONS. ELECTRICIAN TO DETERMINE EXACT REQUIREMENTS IN THE FIELD PER CURRENT NEC AND LOCAL CODES AND MAKE APPROPRIATE ADJUSTMENTS. 2.LABELING REQUIREMENTS BASED ON THE 2014 NATIONAL ELECTRIC CODE, OSHA STANDARD 19010.145, ANSI Z535. 3.MATERIAL BASED ON THE REQUIREMENTS OF THE AUTHORITY HAVING JURISDICTION. 4.LABELS TO BE OF SUFFICIENT DURABILITY TO WITHSTAND THE ENVIRONMENT INVOLVED [NEC 110.21] 5.LABELS TO BE A MINIMUM LETTER HEIGHT OF 3/8", WHITE ON RED BACKGROUND; REFLECTIVE, AND PERMANENTLY AFFIXED [IFC 605.11.1.1] 6.STATE LABELS SHALL BE WEATHERPROOF, DURABLE, AND PERMANENTLY MOUNTED ON LABEL DETAILS SHEETS 3 4 1 ## ### # # LABEL 12 PLACARD TO BE PLACED AT AC DISCONNECT PER XCEL ENERGY. UTILITY AC DISCONNECT LABEL 15 PLACARD TO BE PLACED AT PRODUCTION METER PER XCEL ENERGY.PRODUCTION METER JB M MSP AC PV C SITE INFORMATION: Thomas Mcconnell 20975 Goodhue Way, Lakeville, MN 55044 MAX CONTINUOUS AC SYSTEM SIZE: 3.836 kW AC DC SYSTEM SIZE: 4.48 kW DC Lat, Long: 44.6454603 , -93.2203368(14) Silfab SIL-320 NL PV MODULES(7) AP Systems YC600 INVERTERSCONTRACTOR INFORMATION:Everlight Solar ConstructionPO Box 930550Verona, WI 53593License# DCQ-111802116833.786.4387 ext. 701Xcel Energy MNPOWER TO THIS BUILDING IS ALSO SUPPLIED FROM ROOF MOUNTED SOLAR ARRAYS WITH SAFETY DISCONNECTS AS SHOWN: CAUTION DIRECTORY PERMANENT PLAQUE OR DIRECTORY PROVIDING THE LOCATION OF THE SERVICE DISCONNECTING MEANS AND THE PHOTOVOLTAIC SYSTEM. (ALL PLAQUES AND SIGNAGE WILL BE INSTALLED AS OUTLINED WITHIN: NEC 690.56(B)&(C), [NEC 705.10]) DATE: November 2, 2020 PV08 PAGE: SHEET NAME: PLACARD DRAWN BY: SoloCAD 20975 Goodhue Way, Lakeville MN 55044 FRONT OF HOME PV ARRAY MAIN DISTRIBUTION UTILITY DISCONNECT RAPID SHUTDOWN AC DISCONNECT SWITCH SITE INFORMATION: Thomas Mcconnell 20975 Goodhue Way, Lakeville, MN 55044 MAX CONTINUOUS AC SYSTEM SIZE: 3.836 kW AC DC SYSTEM SIZE: 4.48 kW DC Lat, Long: 44.6454603 , -93.2203368(14) Silfab SIL-320 NL PV MODULES(7) AP Systems YC600 INVERTERSCONTRACTOR INFORMATION:Everlight Solar ConstructionPO Box 930550Verona, WI 53593License# DCQ-111802116833.786.4387 ext. 701Xcel Energy MNDATE: November 2, 2020 PV09 PAGE: SHEET NAME: SITE PHOTOS DRAWN BY: SoloCAD SITE PHOTOS: SITE INFORMATION: Thomas Mcconnell 20975 Goodhue Way, Lakeville, MN 55044 MAX CONTINUOUS AC SYSTEM SIZE: 3.836 kW AC DC SYSTEM SIZE: 4.48 kW DC Lat, Long: 44.6454603 , -93.2203368(14) Silfab SIL-320 NL PV MODULES(7) AP Systems YC600 INVERTERSCONTRACTOR INFORMATION:Everlight Solar ConstructionPO Box 930550Verona, WI 53593License# DCQ-111802116833.786.4387 ext. 701Xcel Energy MNDATE: November 2, 2020 PV10 PAGE: SHEET NAME: TEST PROCEDURE DRAWN BY: SoloCAD CASE #: 04041202 Tech BriefSolar Is Not Always SunnyOver their lifetime, solar panels experience countless extreme weather events. Not just the worst storms in years, but the worst storms in 40 years. High winds capable of ripping panels from a roof, and snowfalls weighing enough to buckle a panel frame. XR Rails are the structural backbone preventing these results. They resist uplift, protect transfer loads into the building structure. Their superior spanning capability requires fewer roof attachments, reducing the number of roof penetrations and the amount of installation time.XR Rail FamilyForce-Stabilizing CurveSloped roofs generate both vertical and lateral forces on mounting rails which can cause them to bend and twist. The curved shape of XR Rails is specially designed to increase strength in both directions while resisting the twisting. This unique feature ensures greater security during extreme weather and a longer system lifetime.Compatible with Flat & Pitched RoofsRoof Mount utilizes XR Rails, along with optional all-in-one attachments, against residential roofs.Corrosion-Resistant MaterialsXR Rails are compatible with FlashFoot and other pitched roof attachments.IronRidge offers a range of tilt leg roof mounting applications.All XR Rails are made of 6000-series aluminum alloy, then protected with an and structural corrosion, while also providing a more attractive appearance. XR Rail Familydesign loads, while minimizing material costs. Depending on your location, there is an XR Rail to match. © 2014 IronRidge, Inc. All rights reserved. Visit www.ironridge.com or call 1-800-227-9523 for more information. Version 1.13Tech BriefRail SelectionThe following table was prepared in compliance with applicable engineering codes and standards. Values are based on the following criteria: ASCE 7-10, Roof Zone 1, Exposure B, Roof Slope of 7 to 27 degrees and Mean LoadRail SpanSnow (PSF) Wind (MPH)4’5’ 4”6’ 8’ 10’ 12’None100120140XR10 XR100 XR100016010-20100120140160301001604010016050-70 16080-90 160XR100XR100 is the ultimate residential mounting rail. It supports a range of wind and snow conditions, while also maximizing spans up to 8 feet.• 8’ spanning capability• Heavy load capability• • Internal splices availableXR10rail, designed for regions with light or no snow. It achieves 6 foot spans, while remaining light and economical.• 6’ spanning capability• Moderate load capability• • Internal splices availableXR1000XR1000 is a heavyweight among solar mounting rails. It’s built to handle extreme climates and spans 12 feet or more for commercial applications.• 12’ spanning capability• Extreme load capability• • Internal splices available THESE SHEETS, DESIGNS, AND SPECS ARE PROPERTY OF SUN INCORPORATED. NO PART SHALL BE DUPLICATED OR USED FOR NONE OTHER THAN ITS SPECIFIC PROJECT WITHOUT WRITTEN CONSENT FROM SUN INCORPORATED.MOUNT SHEETSheet: 5File: \\SUN-SERVER\Sun Incorporated Jobs Master\Equipment\MOUNTS\QUICK MOUNT\QMPV-datasheet-QMHSS-LS-QuickHookSM-web.pdfMissing or invalid referenceSheet: 2File: \\SUN-SERVER\Sun Incorporated Jobs Master\Equipment\MOUNTS\QUICK MOUNT\QMPV-datasheet-QMHSS-LS-QuickHookSM-web.pdfMissing or invalid reference July 19, 2019 Page 1 of 17 Rev 3.1 Xcel Energy Requirements for DER Application Completeness Review Applicable to All Xcel Energy Operating Companies July 19, 2019 Page 2 of 17 Rev 3.1 Table of Contents 1.0 Scope ................................................................................................................................................ 3 2.0 Terms and References ..................................................................................................................... 3 2.1 Glossary ........................................................................................................................................ 3 2.2 References .................................................................................................................................... 3 3.0 One Line Diagram ............................................................................................................................. 4 4.0 Site Plan............................................................................................................................................ 6 5.0 Label Details ..................................................................................................................................... 8 6.0 Test Procedure ................................................................................................................................. 8 7.0 FERC SGIP-Based Interconnection Process Track Eligibility Determination .................................. 10 7.1 Simplified Process ...................................................................................................................... 10 7.2 Fast Track Process ...................................................................................................................... 10 7.3 Study Process ............................................................................................................................. 11 8.0 FERC SGIP-Based Interconnection Process Material Modification Determination ....................... 12 9.0 Revision History ............................................................................................................................. 14 10.0 Document Dependencies ............................................................................................................... 14 10.1 Internal Documents ................................................................................................................ 14 10.2 External Documents ............................................................................................................... 14 Appendix A – Template for Notice of Incomplete Initial Application Materials ...................................... 15 July 19, 2019 Page 3 of 17 Rev 3.1 1.0 Scope Outlined below are the engineering documents and associated minimum requirements for a Distributed Energy Resource (DER) interconnection application to be deemed complete. The requirements apply to all DER for the purpose of providing additional detail on how application completeness will be reviewed with respect to governing interconnection requirements. Interconnections using Energy Storage Systems must also follow the Xcel Energy Storage Interconnection Guidelines in addition to the below requirements. In the context of this document, “Dedicated Power Production Facility” refers to interconnections that connect directly to the Distribution System for the sole purpose of exporting energy to the distribution system and do not have electrical services associated with serving a customer load or premise. Appendix A – Template for Notice of Incomplete Initial Application Materials provides a notification template for communicating with Interconnection Customers when their initial application cannot be deemed complete in accordance with this document. 2.0 Terms and References Applicable terms and company/industry references are provided below. 2.1 Glossary Distributed Energy Resource (DER): Distributed Energy Resources (DERs) include all sources, including energy storage systems. All sources interconnected in parallel with Xcel Energy’s system require an interconnection review. Reference Point of Applicability: The location, either the Point of Common Coupling or the Point of DER Connection, where the interconnection and interoperability performance requirements specified in IEEE 1547 apply. With mutual agreement, the Area EPS Operator and Customer may determine a point between the Point of Common Coupling and Point of DER Connection. See Minnesota DER Technical Interconnection and Interoperability Requirements for more information. 2.2 References 1. Colorado Rule 3667 2. Xcel Energy Section 9 Tariff 3. Xcel Energy Section 10 Tariff 4. New Mexico Interconnection Manual 5. South Dakota PUC Small Generator Facility Interconnection Rules Section 20.10.36 6. Xcel Energy Standard for Electric installation and Use 7. Xcel Energy Storage Interconnection Guidelines 8. National Electric Code 9. UL 1741 July 19, 2019 Page 4 of 17 Rev 3.1 10. IEEE 1547 3.0 One Line Diagram One-Line diagram, also known as a single-line diagram, showing the installation of the DER system and associated equipment shall be required with each interconnection application. To reduce the chances of a delayed deemed-complete status by increasing the overall clarity of the one-line, it is strongly recommended to use a standard graphical symbol set, such as that found in IEEE 315, when such a standardized symbol exists. The following information shall be clearly depicted on the one-line diagram: Contact information and General 3.1 Name of Customer who owns/will own service, the Xcel Energy “customer of record” for existing services 3.2 Application OID, SRC, or case number assigned to the project 3.3 Clearly identify the Reference Point of Applicability (RPA) and denote the RPA where test and verification features will be applied in the written test procedure 3.4 A note indicating that the design shall meet National Electric Code (NEC codes) requirements 3.5 For systems larger than 250 kW, a signature from a professional engineer licensed in Minnesota is required. Electrical Component Schematic 3.6 Label and show the electrical layout of all equipment in-line between the main service meter and the DER system 3.6.1 The equipment listed shall include, at a minimum, switches, breakers, fuses, junction boxes, combiner boxes, protective devices, etc. 3.6.2 All customer equipment1 shall be located on the customer-side of the main service meter 3.6.2.1 Primary vs secondary interconnection shall be clearly noted and consistent with all other provided documentation 3.7 Main service meter and main service panel 3.8 Main service protection2 between DER and the utility 3.8.1 The protective device shall be provided immediately after the main service meter 3.9 Electrical ratings3 of all equipment 3.10 The aggregate AC capacity of each DER system 3.11 The electrical ratings of the DER shall be provided 1 Xcel Energy infrastructure is not required to be shown on the customer one-line. Any Xcel Energy equipment shown is subject to change and should not be used for planning/design purposes by the customer 2 For DER being installed on existing buildings, the main service breaker will typically be sufficient 3 Including, but not limited to, Volts, Amps, number of phases, kW, kVA, winding configurations July 19, 2019 Page 5 of 17 Rev 3.1 3.11.1 Voltage 3.11.2 Power Output (KVA or kW) 3.11.3 Phases (single or three-phase inverters) 3.12 Clearly note if inverter(s) are UL1741 certified 3.13 When multiple DER units are existing or proposed on a single service: all DER systems shall be shown with proposed and existing marked 3.14 For energy storage systems: the mode of operation4 being applied for shall be clearly indicated on the one-line 3.15 The circuit for auxiliary equipment power necessary to the operation of the DER shall be shown 3.16 The Reference Point of Applicability shall be indicated Metering 3.17 Production meter, if applicable, with ownership noted (utility or customer) 3.17.1 For single-phase installations, the meter shall be specified as 1-phase, 3-wire 3.17.2 For three-phase installations, the meter shall be specified as 3-phase, 4-wire 3.17.3 No loads or energy storage systems shall be connected on the DER side of the production meter. 3.17.4 All Xcel-owned production meters shall be installed at an Xcel Energy standard voltage5 3.17.5 Production Meter CT polarity should be shown on the drawing as facing the PV, i.e. H1 of the CT faces the inverter such that DER is seen by the production meter as kWh delivered 3.17.6 When present, customer owned meters shall be clearly noted as “provided by customer” 3.17.6.1 Customer owned meters shall not be located on the DER side of the Xcel Energy production meter6 3.18 For systems with an output of 200 amps or more: any Xcel-owned metering requiring PTs shall be shown with the PTs unfused AC Disconnect 3.19 A visible-open type, lockable, and readily accessible AC disconnect for purposes of isolating the DER from the utility source labeled “Utility AC Disconnect,” “Photovoltaic Utility AC Disconnect,” or similar shall be shown 3.19.1 Other AC Disconnects shall not be labeled or identified as a “Utility” AC Disconnect, if applicable 4 Reference the Xcel Energy Guidelines for Interconnection of Electric Energy Storage found on Xcel Energy’s website for the full requirements of Energy Storage applications 5 Xcel Energy standard service voltages can be found on Pg. 24, section 3.1.1 of the Electric Standard For Electric Installation and Use. The inverter side of a step-up transformer may be a non-standard Xcel Energy voltage, provided that no Xcel Energy metering is located between the step-up transformer and the inverter 6 Refer to applicable state interconnection tariffs and program rules to determine if production meters are applicable July 19, 2019 Page 6 of 17 Rev 3.1 3.19.2 If the AC disconnect is not located within 10 feet of the main service meter7, a label meeting all requirements of the “Label Details” section should be placed at the main service meter clearly showing the location of the AC Disconnect 3.19.3 For installations that require a Production Meter, the Utility AC Disconnect shall be located between the DER and production meter 3.19.4 For installations not requiring a Production Meter, the Utility AC Disconnect shall be located between the DER and main service 3.19.5 When multiple DER units are existing or proposed on a single service: if a single Utility AC Disconnect cannot be used to disconnect all DER, all Utility AC Disconnects should include numerical identification such as “Utility AC Disconnect 1 of 2” or similar. The number of disconnects required to be operated to isolate the DER from the utility should be clear. Ground Referencing (applies only to systems greater than 100 kW) 3.20 Ground referencing8 equipment shall be installed between the main service meter and production meter to provide a ground reference for the system 3.20.1 Details of the ground reference equipment required on the one-line: 3.20.1.1 Type/winding configuration of ground referencing equipment 3.20.1.2 X0 value 3.20.1.3 X0/R0 ratio 3.20.1.4 Neutral current rating 3.20.1.5 Equipment fault withstand rating 3.20.2 Loss of ground referencing equipment shall immediately trip the DER system offline 3.20.2.1 The method of monitoring and tripping shall be shown on the one-line 4.0 Site Plan Site Plan or location plan identifying location of equipment noted on the one line shall show the following information: Contact Information and General 4.1 Name of Customer who owns/will own the service, the Xcel Energy “customer of record” for existing services 4.2 Installation premise address 4.2.1 Installation address shall match application address 7 This will be evaluated as an exception, which may or may not be approved based on the accessibility of the AC Disconnect or the clarity of the placard 8 See the “PV and Inverter-based DER Ground Referencing Requirements and Sample Calculations” document for ground reference requirements July 19, 2019 Page 7 of 17 Rev 3.1 4.2.2 Installation address shall match the premise address for existing customer/services 4.2.3 For dedicated power production facility interconnection applications: GPS Coordinates in WGS 94 decimal degrees, with municipality and county are acceptable in place of an address when one has not yet been established by the county 4.3 Installer name & contact information 4.4 Application OID, SRC, or case number assigned to the project 4.5 Building(s) and streets shall be labelled 4.5.1 A minimum of one street should be included on the site plan, with the name, distance, and direction to the nearest cross street, if the nearest cross street is not shown 4.6 Compass direction (indicate North) 4.7 For ground mounted systems: an access road is required to all Xcel Energy equipment, including production metering and Utility AC disconnects. For systems smaller than 100 kW, an exception may be sought for this requirement, based on equipment location and accessibility. 4.7.1 The width of this road shall be indicated and cannot be less than 12 feet wide 4.7.2 The drawing shall show the route from a public road to the Xcel Energy equipment Electrical Component Locations 4.8 Main service entrance, all meter locations, disconnects, transformers, proposed and existing DER systems 4.8.1 Distance shall be noted between this equipment 4.8.2 Primary vs secondary interconnection shall be clearly noted and consistent with all other documentation 4.8.3 For dedicated power production facilities: when an overhead primary service interconnection is used, the customer pole shall be no less than 25’ from the Xcel Energy meter pole. Typical acceptable distance from the Xcel Energy meter pole to the customer pole is 40’ 4.9 The Production Meter and AC Disconnect should be located together in a readily accessible location within 10’ of the main service meter 4.9.1 If the AC disconnect or Production Meter is not located within 10 feet of the main service meter9, a label meeting all requirements of the “Label Details” section should be placed at the main service meter clearly showing the location of the AC Disconnect 4.10 24/7 unescorted keyless access shall be provided to all Xcel Energy equipment 4.11 Position, distance and clearance concerns of overhead electric service lines and/or other utilities in relation to the PV panels shall be noted 9 This will be evaluated as an exception, which may or may not be approved based on the accessibility of the AC Disconnect or the clarity of the placard July 19, 2019 Page 8 of 17 Rev 3.1 4.12 A separate Detail View or Plan View may be required to clearly show location of meters, main service and AC disconnect, when the site layout is unclear or illegible when printed on an 11”x17” sheet 5.0 Label Details 5.1 Labels shall be weatherproof, durable and permanently mounted 5.2 Labels shall demonstrate or state compliance with NEC 690 5.3 A label shall be included on Main Service Meter with the text “Generation System Connected”, or similar 5.3.1 When an Energy Storage System (ESS) is present, include a label stating that an ESS is present and equipped with an auto-transfer switch 5.4 Include label “Utility AC Disconnect”, or similar 5.4.1 When multiple DER units are present, if a single Utility AC Disconnect cannot be used to disconnect all DER, all Utility AC Disconnects should include numerical identification such as “Utility AC Disconnect 1 of 2” or similar. The number of disconnects required to be operated to isolate the DER from the utility should be clear. 5.5 When multiple DER units are existing or proposed on a single service: equipment for each system shall be uniquely identified through labelling (i.e. “PV Unit 1 of 2” or similar) 6.0 Test Procedure A test procedure that will be used to verify the DER to grid interface protection and operation of the DER system shall be submitted to Xcel Energy for approval. The procedure shall include an open-phase test (for three phase systems) and an unintentional island detection test (for all systems) to verify the system ceases generating in parallel with the Xcel Energy distribution system when the Utility source is lost. Each system is unique and will require a custom test procedure based on the DER10. In addition to the manufacturer’s recommendations, the following steps or notes shall be included: Contact Info and General 6.1 Name of Customer who owns service, the Xcel Energy “customer of record” for existing services 6.2 Installation premise address shall match application address 6.2.1 Address shall match the premise address for existing customer/services 6.3 Application OID, SRC, or case number assigned to the project 6.4 A note stating “All testing shall be performed by qualified personnel” 10 DER Owners may wish to consult with the Manufacturer regarding considerations specific the DER unit of interest. July 19, 2019 Page 9 of 17 Rev 3.1 Testing Applicable to all DER 6.5 The procedure shall provide steps to verify fixed power factor settings for each inverter meet the project requirements 6.6 The unintentional islanding test shall at minimum contain the following steps: 6.6.1 Steps that verify DER system is ready to be energized 6.6.2 Steps to verify labeling for the Main Service Panel, DER Protection, DC Disconnect, AC disconnect, Utility AC disconnect, Production Meter (when applicable) and other relevant labelling and signage 6.6.3 Steps to energize the DER system 6.6.4 While in normal operation, steps to verify the voltages at the DER AC terminals are within 5% of the combined DER AC voltage ratings and all LEDs, alarms, and/or LCD codes are “normal” 6.6.5 While in normal operation, steps to verify that all DER units are operational and producing power 6.6.6 Steps to simulate the loss of utility source11 for the unintentional islanding test shall be listed 6.6.6.1 Clearly identify the disconnection device being used to simulate this utility power outage 6.6.7 Using a voltmeter, verify the voltage at the inverter side of the AC disconnect has dropped to zero 6.6.7.1 Only customer-owned equipment shall be used for this verification. Xcel Energy will not provide special equipment for this verification. Xcel Energy provided meters shall not be used for this verification. 6.6.8 Using an ammeter or the DER’s display/metering, verify the DER has ceased to energize within two seconds. For three phase systems, three phase monitoring may be required. 6.7 Verify DER LEDs, alarms, and/or LCD codes are appropriate for loss of Utility source 6.8 Steps to restore the lost Utility source shall be listed 6.9 A step to verify that the inverter system delays five (5) minutes before resuming power output after the Utility source is restored shall be listed Testing Applicable only to Three-Phase systems 6.10 For three-phase systems, steps to simulate an open phase condition from the utility shall be included. The device used to create an open phase shall be clearly identified in the procedure. 6.10.1 If ground referencing equipment is present, the open point must occur upstream of this device (upstream meaning in the direction of the utility source) 11 This typically involves opening an AC disconnect. July 19, 2019 Page 10 of 17 Rev 3.1 6.10.2 If the protection scheme used to detect the open phase uses devices other than the inverter (for instance, separate relaying to trip a VFI or breaker), the installer must provide an engineering analysis that demonstrates a non-detection zone does not exist when the output of the DER is 5% or greater of the aggregate inverter AC nameplate rating in the open-phase detection schemes. A step will be required to disable this setting during testing if an acceptable engineering analysis cannot be provided. 6.11 Steps to verify voltage and current are to be listed for the open-phase test. Location of measurement points shall be identified. 7.0 FERC SGIP-Based Interconnection Process Track Eligibility Determination For those states and Operating Companies using interconnection procedures based on the FERC Small Generator Interconnection Process (SGIP), it is necessary to verify an Interconnection Customer has correctly selected the appropriate interconnection application review process. Process tracks are tied to application fees and review timelines. 7.1 Simplified Process To qualify for the simplified interconnection process, the proposed DER must utilize a certified inverter based equipment package. Compliance with the UL1741 certification is likely indicated by the Interconnection Customer on the application form, but shall still be verified by an engineering review of the provided documentation. Simplified process thresholds are as follows for SGIP based states: 7.1.1 Colorado: 10kW or less 7.1.2 Minnesota: 20kW or less 7.1.3 New Mexico: 10kW or less 7.1.4 South Dakota: 10kW or less 7.2 Fast Track Process Interconnection applications for the fast track process may utilize certified or non-certified equipment. Process thresholds vary by state as follows: 7.2.1 Colorado: Maximum DER size is no larger than two (2) MW. Also note the proposed DER shall meet the codes, standards, and certification requirements as noted in the rules. 7.2.2 Minnesota: Section 3.1 of the Minnesota Interconnection Procedures (MIP) provides detail around fast track process thresholds. Note that synchronous and induction machines are always limited to two (2) MW or less in order to be fast track eligible. For inverter-based generation, use information available in GIS to determine feeder line voltage and distance in line miles to the appropriate substation, then input those values July 19, 2019 Page 11 of 17 Rev 3.1 into Table 1. For process eligibility, the mainline should be considered to be the main trunk of the circuit protected from a substation protective device. Fast Track Eligibility for Distributed Energy Resources Line Voltage Fast Track Eligibility12 Regardless of Location Fast Track Eligibility for certified, inverter-based DER on a Mainline13 and ≤2.5 Electrical Circuit Miles from Substation14 <5 kV ≤500 kW ≤500 kW ≥5 kV and <15 kV ≤1 MW ≤2 MW ≥15 kV and <30 kV ≤3 MW ≤4 MW ≥30 kV and ≤69 kV ≤4 MW ≤5 MW Table 1 - Process Eligibility Determination 7.2.3 New Mexico: Maximum DER size is no larger than two (2) MW. Also note the proposed DER shall meet the codes, standards, and certification requirements as noted in the state interconnection manual. 7.2.4 South Dakota: Maximum DER size is no larger than two (2) MW. Additional considerations are outlined in the Tier 2 and Tier 3 process requirements. 7.3 Study Process Interconnection requests not meeting eligibility requirements of the simplified or fast track processes will typically require a more detailed engineering study. Subject to the limits in 7.3.1 to 7.3.4, these projects will follow their respective state rules and tariffs for interconnection technical review. 7.3.1 Colorado: For DER interconnections between two (2) MW and no larger than ten (10) MW, and any interconnection application that fails the review screens of Level 1 or Level 2 processes. 7.3.2 Minnesota: For DER applications up to ten (10) MW that do not qualify for simplified or fast track processes, or that fail the initial and supplemental review screens. 12 Synchronous and induction machines eligibility is limited to no more than 2MW even when line voltage is greater than 15 kV. 13 For purposes of this table, a Mainline is the three-phase backbone of a circuit. It will typically constitute lines with wire sizes of 4/0 American wire gauge, 266 kcmil, 336.4 kcmil, 397.5 kcmil, 477 kcmil and 795 kcmil. 14 An Interconnection Customer can determine this information about its proposed interconnection location in advance by requesting a pre-application report pursuant to MIP Section 1.4. July 19, 2019 Page 12 of 17 Rev 3.1 7.3.3 New Mexico: For DER interconnections up to ten (10) MW that either do not qualify for or fail the initial review screens contained in simplified and fast track processes. 7.3.4 South Dakota: For DER interconnections up to ten (10) MW that do not qualify for or fail the initial review screens of the Tier 1, 2, or 3 processes. 8.0 FERC SGIP-Based Interconnection Process Material Modification Determination For those states and Operating Companies using interconnection procedures based on the FERC Small Generator Interconnection Process (SGIP), it is necessary to determine whether changes to a DER proposed by an Interconnection Customer constitute a Material Modification. Material Modifications encompass any changes to an interconnection application which has been deemed complete that alter machine data, equipment configuration, or site layout. Specifically, such changes must have a material impact on cost, timing, or design of interconnection facilities15 or upgrades16 on the project under consideration or any later queued project. Material Modifications may also impact the safety or reliability of the Company’s system. Material Modifications apply to DER units after they are granted permission to operate. A Material Modification shall include: 1) Changes the physical location of the point of common coupling; such that it is likely to have an impact on technical review; 2) Increases the nameplate rating or output characteristics of the Distributed Energy Resource; 3) Changes or replaces generating equipment, such as generator(s), inverter(s), transformers, relaying, controls, etc., and substitutes equipment that is not like-kind substitution in certification, size, ratings, impedances, efficiencies or capabilities of the equipment; 4) Changes transformer connection(s) or grounding; and/or 5) Changes to a certified inverter with different specifications or different inverter control settings or configuration. 15 Interconnection Facilities – The Company’s Interconnection Facilities and the Interconnection Customer’s Interconnection Facilities. Collectively, Interconnection Facilities include all facilities and equipment between the DER and the Point of Common Coupling, including any modification, additions or upgrades that are necessary to physically and electrically interconnect the DER to the Company’s System. Some examples of Customer Interconnection Facilities include: supplemental DER devices, inverters, and associated wiring and cables up to the Point of DER Connection. Some examples of Company Interconnection Facilities include sole use facilities; such as, line extensions, controls, relays, switches, breakers, transformers and shall not include Distribution Upgrades or Network Upgrades. 16 Upgrades – The required additions and modifications to the Company’s Transmission or Distribution System at or beyond the Point of Interconnection. Upgrades may be Network Upgrades or Distribution Upgrades. Upgrades do not include Interconnection Facilities. July 19, 2019 Page 13 of 17 Rev 3.1 A Material Modification shall NOT include: 1) Changes the ownership of a Distributed Energy Resource; 2) Changes the address of the Distributed Energy Resource, so long as the physical point of common coupling remains the same; 3) Changes or replaces generating equipment such as generator(s), inverter(s), solar panel(s), transformers, relaying, controls, etc. and substitutes equipment that is a like-kind substitution in certification, size, ratings, impedances, efficiencies or capabilities of the equipment; and/or 4) Increases the DC/AC ratio but does not increase the maximum AC output capability of the Distributed Energy Resource in a way that is likely to have an impact on technical review. July 19, 2019 Page 14 of 17 Rev 3.1 9.0 Revision History Revision Date Prepared By Approved By Notes 2.0 JCH Converted to standard format/layout, added several sections 10.0 Document Dependencies 10.1 Internal Documents 1. Colorado Rule 3667 2. Xcel Energy Section 9 Tariff 3. Xcel Energy Section 10 Tariff 4. New Mexico Interconnection Manual 5. South Dakota PUC Small Generator Facility Interconnection Rules Section 20.10.36 6. Xcel Energy Standard for Electric installation and Use 7. Xcel Energy Storage Interconnection Guidelines 10.2 External Documents 1. National Electric Code 2. UL1741 July 19, 2019 Page 15 of 17 Rev 3.1 Appendix A – Template for Notice of Incomplete Initial Application Materials If a DER interconnection application is incomplete, complete the form on the following page and provide a copy to the responsible Program Manager. The Program Manager will then communicate with the Interconnection Customer to address any issues within the required timeframe. Save a copy of this form in the appropriate engineering folder for the project. July 19, 2019 Page 16 of 17 Rev 3.1 July 19, 2019 To Whom it May Concern: Regarding your DER interconnection request for application number(s): ____________________________________________________________________________________ in the state of ___________________________, we are writing to inform you that one or more aspects of your application are not complete and require action to update before we can proceed with more detailed engineering reviews. Missing information is noted below under the relevant section heading. Section 3.0 One Line Diagram Section 4.0 Site Plan Section 5.0 Label Details July 19, 2019 Page 17 of 17 Rev 3.1 Section 6.0 Test Procedure Section 7.0 FERC SGIP-Based Interconnection Process Track Eligibility Determination Are provided UL1741 certification documents sufficient: ☐ Yes ☐ No Please update your relevant application documents and resubmit for Xcel Energy review in accordance with the governing interconnection process timelines.