Minnesota DER Interconnection Process

Kristi Robinson, P.E.

6841 Power Lane SW • Alexandria, Minnesota Tel 320.762.1697 • Fax 320.762.1479

www.star-energy.com • eee@star-energy.com

• Spring 2017: Petition made to update existing MN Interconnection Process

• PUC agreed to update interconnection process and said the FERC Small Generator Interconnection Process (SGIP) would be the basis of the new interconnection process

• Process to update MN Interconnection Process would be in two phases: • Phase I – Interconnection Process• Phase II – Technical Requirements

• Summer – Fall 2018: Multiple stakeholder group meetings on Phase I

• Winter 2017/2018: PUC releases Minnesota Distributed Energy Resources Interconnection Process (MN DIP) and Minnesota Distributed Energy Resource Interconnection Agreement (MN DIA)

• Spring 2018: Phase II stakeholder group meetings begin

• May 2018: PUC hearing on MN DIP and MN DIA• PUC order has the new MN DIP and MN DIA in effect as of

June 17th, 2019

• Interconnection Tracks: Simplified, Fast Track and Study

• Timelines: New timelines that include response steps from the Applicant. Also has interconnection contract being sent to Applicant within 5 days of approval of application.

• Queues: A utility with 40+ applications in a year will need to maintain a public queue of active interconnection applications

Distribution Energy Resource (DER): Formally known as Distributed Generation (DG). DER includes storage along with renewable and fossil fuel generators

Point of Coupling/Connection:

Capacity: In most cases Nameplate Capacity of DER device. For systems with multiple DER devices and controls, the controls can be the limiting capacity factor

**Disclaimer: Capacity is not yet defined by PUC**

Application Agent: Vendor or person who is given permission to act on the DER owner’s behalf during the interconnection process. CAN NOT SIGN CONTRACTS OR APPLICATIONS

Interconnection Customer: The owner of the proposed DER system and the entity requesting interconnection to the distribution system

Area EPS Operator: The utility who is operating the distribution system

DER Interconnection Coordinator: A person(s) at the utility who is the single point of contact for general information regarding the interconnection process

For majority of utilities the Fast Track limits DER size to 2 MW

• Potential Interconnection Customers can call the Utility and ask for assistance determining process track and request additional, readily available information about a specific location

• Specific, detailed informational request should be made by a Pre-Application Report› $300 fee is required with a Pre-Application Request› Utility must only provide different sets of data if the data

is readily assessible

Utilities that have more than 40 completed interconnection applications per year shall maintain a public queue

Fast Track Process

Application Submitted

Interconnection Customer Notified that Application is Deemed

Incomplete

10 Days

5 Days

Submit Missing Information

Interconnection Customer Notified

Application is Approved or Moved to Fast Track

10 Days

INTERCONNECTION CUSTOMER

UTILITY

MIA or Uniform Contract sent to Interconnection

Customer

5 Days

• Aggregate generation on circuit shall not exceed:• 15% of annual peak load of line section • 100% of daytime minimum load of line section (solar)• 100% of substation minimum load

• Aggregate generation on circuit shall not contribute more than 10% to circuit’s maximum fault current

• Aggregate generation on circuit shall not cause any distribution protective devices to exceed 87.5% of short circuit interruption capabilities

• If interconnected on single-phase shared secondary, aggregate generation on shared secondary shall not exceed 20 kW or 65% of transformer nameplate rating

• If proposed interconnection on load side of network protector, DER must be inverter-based and shall not exceed 5% of network’s maximum load and 50 kW.

• If DER is single-phase and interconnection on center tap neutral of 240 volt service, DER shall not create imbalance between the two sides of 240 volt service of more than 20% of transformer nameplate rating

Study Process

Study Process

Application Submitted

Interconnection Customer Notified that Application is

Deemed Incomplete

10 Days

10 Days

Submit Missing Information

Interconnection Customer Notified Application is

Approved, Supplemental Studies Needed or Moved

to Study Track

5 Days

INTERCONNECTION CUSTOMER

UTILITY

5 Days

MIA or Uniform Contract sent to Interconnection

Customer

Deeper review on:• Minimum Load• Voltage & Power Quality• Safety & Reliability

Interconnection Customer chooses order of topic reviews and chooses what will happen if an additional topic review shows screens still fails

Estimated cost for supplemental review is paid for upfront

DER System > 4 MW or DER System that fail screens in other tracks

• Once the Interconnection Application is approved the Utility must send an interconnection contract to the member within 5 business days

• Contract must be signed by member and returned to Utility within 30 business days

• Can not interconnect DER system unless signed contract is returned to Utility, 5 days prior to commissioning

• Created Cooperative/Municipal Minnesota Distributed Energy Resource Interconnection Process (C-MIP & M-MIP)

• Follows timelines, principles and concepts laid out in MN DIP

• Breaks MN DIP into 4 separate documents

• Spring – Fall 2018: Technical Stakeholder Subgroup meeting via web conference on updating Minnesota’s technical requirements for DER• Main, over arching requirements are listed in the Technical

Interconnection and Interoperability Requirements (TIIR) document

• Each utility will develop Technical Specification Manuals (TSM) listing specific technical details that are custom to that utility

• Still an ongoing process!!!!

In TIIR• Performance Category Assignment• Using Default Parameters• Protection Requirements• Reactive, Voltage/Power Control Performance• Default Response to Abnormal Conditions

In TSM• Metering specifics• Communications specifics• Defined types of test for interconnection• Specifics for when defaults are overrode and specified by utility

• Interconnection Requirement are to harmonize with IEEE 1547

• Waiting on IEEE 1547.1 for further guidance

• Most likely final TIIR available Q2/Q3 2019

• PUC docket process to hold additional comment period and hearing

• Expecting an interim period between total harmonization between MN DIP, MN DIA, TIIR, IEEE 1547 and certified equipment

STAR Energy Services LLC6841 Power Lane SWAlexandria, MN 56308

Tel: 218.405.0228Email: krobinson@star-energy.com