HomeMy WebLinkAboutLA188530 -19777 Hazel Nut Ave 2.24.21Wyssling Consulting
76 North Meadowbrook Drive
Alpine, UT 84004
Scott E. Wyssling, PE, PP, CME office (201) 874-3483
swyssling@wysslingconsulting.com
February 19, 2021
Everlight Solar Construction PO Box 930550 Verona, WI 53593
Re: Engineering Services Warner Residence 19777 Hazel Nut Avenue, Lakeville, MN 6.028 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 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 C 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 t IronRidge Solar Installation Manual 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 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 threa imum
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 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
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 Jo s Master E uipment MOUNTS QUICK MOUNT QMPV-datasheet-QMHSS-LS-Quic Hoo SM-we .pd Missing or invalid re erenceSheet: 2File: SUN-SERVER Sun Incorporated Jo s Master E uipment MOUNTS QUICK MOUNT QMPV-datasheet-QMHSS-LS-Quic Hoo SM-we .pd Missing or invalid re erence
July 19, 2019 Page 1 of 17 Rev 3.1
July 19, 2019 Page 2 of 17 Rev 3.1
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
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, 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 equipment
1 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 protection
2 between DER and the utility
3.8.1 The protective device shall be provided immediately after the main service meter
3.9 Electrical ratings
3 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 voltage
5
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 meter
7, 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 referencing
8 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 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
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
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 source
11 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 -
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
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
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 Mainline
13
and
Miles from Substation14
<5 kV
and <15 kV
and <30 kV
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
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 -
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 Date Prepared By Approved By Notes
2.0 JCH
Converted to standard
format/layout, added
several sections
10.0
10.1
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
1. National Electric Code
2. UL1741
July 19, 2019 Page 15 of 17 Rev 3.1
–
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.
3.0
4.0
5.0
July 19, 2019 Page 17 of 17 Rev 3.1
6.0
7.0 -nation
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.