Large Scale Solar Integration

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1 Large Scale Solar Integration Experiences and Coming Changes in Distributed Energy Resource Interconnections October 26 th, 2017

2 Overview Background on Xcel Energy Expansion of Solar in Minnesota Changes to Distribution Interconnection Standards Bulk System Support Local System Support Interoperability

3 About Xcel Energy Operate in Eight states Northern States Power Company Minnesota Northern States Power Company Wisconsin Million Electric Customers 1.8 Million Natural Gas Customers Public Service Company of Colorado Southwestern Public Service Company

4 Rapid Expansion of Solar in Minnesota 4

5 Community Solar in Minnesota Legislation For 1 MW Program Opens 2014 Timeline PUC Hearings 2015 Co location Deadline $ for bill credit $ for bill credit 3. Xcel Energy Solar Energy 1. Subscribers How Community Solar Works 2. Community Solar Garden Operator 4. All Customers 5 $

6 Co-location Resulting in 5 MW Plants 6

7 Minnesota Application Process Opens 7

8 MN Solar Gardens Oct 2015 Oct 2017 Applications (MW) Study Study Complete Operational Design and Construction Initial Application Application Withdrawn Waiting for Study Payment 8

9 Minnesota Community Solar Current State 42 solar gardens online today (139.3 MW) Over 600 MW worth of active applications/projects 400+ MW installed by end of 2018? 9

10 Transmission or Distribution Connected? Distribution (DER) Project or Program MW Aurora 100 Community Solar Small Scale 5 Transmission Project Location MW Marshall Solar Marshal MN MN Solar 1 Tracy, MN North Star Solar North Branch, MN Total of 244 MW D T Total of 187 MW Xcel Energy MN Service Territory

11 DER Interconnection Standard Update IEEE

12 Brief History of Interconnections 12 Source: EPRI

13 Adopting the Standard Revision IEEE 1547 IEEE Equipment Certification (UL 1741) State Interconnection Rules Generator Interconnection and Operating Agreements IEEE 1547 is a voluntary standard Typically adopted on statewide basis by regulatory or legislative actions Revised standard supersedes prior version but only applied to new interconnections Relies on additional testing and verification standards (i.e. IEEE , UL 1741)

14 Standard Adoption Timeline Interconnection Standard IEEE 1547 Publication Early 2018 Test Procedures Standard IEEE Completion in Late 2018? Equipment Certification UL 1741 Completion in Early to Mid 2019? Equipment Adoption Equipment Available in Late 2019? 14

15 Revision to Interconnection Standard Important Scope Changes in IEEE P Source: EPRI

16 New Requirements Proposed 16 Source: EPRI

17 IEEE P1547 Performance Category Approach Policy decision to assign performance categories

18 18 Bulk System Support

19 Inverter Impacts on Bulk System Blue Cat Fire in California August 16 th, 2016 Tripping Cause Frequency Measurement Error Undervoltage Overvoltage, DC Overcurrent, Loss of Sync Capacity of Inverter Based Generation Tripped 700 MW 450 MW ~ 50 MW Total of about 1200 MW of PV Generation Tripped 19

20 Historic Voltage Trip Requirements 20 Source: NERC, Performance of Distributed Energy Resources During and After System Disturbance: Voltage and Frequency Ride Through Requirements, North American Electric Reliability Corporation, 2013.

21 Voltage & Frequency Ride-Through Requirements Origins Requirement Category Foundation Justification Voltage Ride Through Category I German grid code for medium voltageconnected synchronous generatorbased DER Essential bulk system needs. Attainable by all state of the art DER technologies. Category II NERC PRC but w/o stability exception, extended LVRT duration for 65 88% V nom based on EPRI White Paper (May 2015) All bulk system needs. Coordinated with existing reliability standards. Considering fault induced delayed voltage recovery. Category III CA Rule 21 and Hawaii, minor modifications All bulk system needs. Considering fault induced delayed voltage recovery. Distribution system operation. Frequency Ride Through All Categories (harmonized) CA Rule 21 and Hawaii, exceeds PRC based on EPRI White Paper (May 2015) All bulk system needs. Low inertia grids. Source: EPRI

22 Ride-Through Requirements Example Voltage, Category III Voltage (p.u.) may ride through or may trip 0.16 s 2 Momentary Cessation Capability Continuous Operation Capability (subject to requirements of clause 5) Mandatory Operation Capability Momentary Cessation Capability 1 s may ride through or may trip 0.50 p.u. 2 2 s 10 s 12 s 1.20 p.u s 1.10 p.u. 50 s p.u s s may ride through or may trip 21 s Legend shall trip range of adustability default value shall trip zones may ride through or may trip zones shall ride through zones and operating regions describing performance 0.88 p.u p.u p.u. shall trip Time (s)

23 Questions on Ride-Through What is the process for developing and implementing ride on a regional basis? Is information on the capacity and tripping characteristics of DER needed for bulk system modeling? 23

24 24 Local System Support

25 DER Impacts on Feeder Voltage Reverse Power Flow from Generator Can Lead to High Voltage 25

26 DER Impacts on Feeder Voltage Watts Vars Two ways DER can reduce voltage 1. Consume Reactive Power (Vars) 2. Reduce Real Power Injection (Watts) 26

27 A Reactive Power Analogy 27 Force Expended Reactive Power (Vars) Force Leading to Work Real Power (Watts)

28 Reactive Power Capability 28

29 Real and Reactive Power Control Capability DER Category Cat A Cat B Voltage Regulation by Reactive Power Control Adjustable Constant Power Factor Mandatory Mandatory Adjustable Constant Reactive Power Mandatory Mandatory Active Power Reactive (Watt Var) Optional Mandatory Voltage Reactive Power (Volt var) Mandatory Mandatory Voltage and Active Power Control Voltage Real Power (Volt Watt) Optional Mandatory

30 Advanced Function Example 1 Voltage Active Power Mode (Volt Watt) Power output reduced when upper voltage limit is reached Reduced power results in lower voltage 30

31 Advanced Function Example 2 Voltage Reactive Power Mode (Volt Var) Reactive power absorption or injection is changed based on voltage Absorbing Vars Lowers voltage Injecting Vars Raises voltage 31

32 32 Interoperability

33 Interoperability Scope 33 Information Models, Protocols, Information exchange

34 Interoperability Mandatory Interface for exchanging information Information to be exchanged: Nameplate Information Configuration Information Monitoring Information Management Information

35 Why Require Interoperability? Monitoring of near real-time status for Operations Remote settings changes for contingency or emergency situations Coordination with advanced distribution applications Distribution Voltage Optimization Fault Location Identification and Service Restoration Integration in Distributed Energy Resources Management (DERMS) Dynamic management of control settings 35

36 Recap Expansion of Solar in Minnesota Changes to Distribution Interconnection Standards Bulk System Support Local System Support Interoperability 36

37 37 Patrick Dalton, P.E. Xcel Energy Sr Engineer, Distributed Energy Resources

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