Xcel Energy Inc. · NASDAQ:XEL
Xcel Energy — Technical Presentation (September 2019)
50 slides from Xcel Energy's technical presentation, Sep 16, 2019
Slide 1: Solar*Rewards Community Subgroup Meeting
Solar*Rewards Community Subgroup Meeting 9/16/2019
Slide 2: Meeting Agenda
Meeting Agenda Welcome & Introductions 1:00 - 1:10 Kevin Cray 4:10 - 1:30 Hosting Capacity Resources Matt Hagan 4:30 — 2:00 Tips & Tricks for Field Identification/Pre-App Jacob Whitaker Data Report Evaulation 2:00 - 2:30 Substation Overview Patrick Kuretich 2:30 - 3:00 SRC Metering Requirements Dave
Slide 3: Hosting Capacity Resources
(2) Xcel Energy’ Hosting Capacity Resources
Slide 4: 2019 MDL Data
2019 MDL Data • Minimum Daytime Load Report updated for 2019 data • Changes to methodology 4
Slide 5: Hosting Capacity Map Updates
Hosting Capacity Map Updates • Fixed bugs related to the map scale • Changed the scale from 4MW to 2MW • Added threshold for reverse power flow at feeder breaker • Still no single phase representation • Still based on 2017 MDL data • Pop-ups are coming 5
Slide 6: Power Flow Model Updates
Power Flow Model Updates • More accurate MDL data means more accurate of power flow model and maps • Using measured voltage data (where available) • 75% of models will be completely rebuilt from scratch to include new GIS data • Better representation of large customers • Connected DER updated in GIS
Slide 7: EPRI DRIVE Tool Updates
EPRI DRIVE Tool Updates • Received V2.0 in June • Reverse Power Flow and Unintentional Islanding thresholds are more dynamic • Results reflect 1, 2, & 3 phase data • Thermal limits now account for fuses too • New Thresholds: Operational Flexibility and 3V0 Transient Overvoltage • Change with Breaker
Slide 8: Looking to the Future
Looking to the Future • Advanced Distribution Management System (ADMS) • 2MW 5MW maximum interconnection size • Looking into more dynamic & interactive map • Layer Package not available yet 8
Slide 9: Tips and Tricks for Field Identification of Distribution System Conductor Size and Capacity/Pre-App Data
Tips and Tricks for Field Identification of Distribution System Conductor Size and Capacity/Pre-App Data Report Evaluation
Slide 10: Distribution System
Distribution System 10
Slide 11: Substation
Substation 11
Slide 12: Substation (Transmission Lines)
Substation (Transmission Lines) 12
Slide 13: Mainline Feeder (Terminal Pole)
Mainline Feeder (Terminal Pole) 13
Slide 14: Overhead Fuse (Tap)
Overhead Fuse (Tap) 14
Slide 15: Fuses
Fuses 15
Slide 16: Reclosers
Reclosers 16
Slide 17: Reclosers
Reclosers Recloser Recloser Control (Says Recloser) 17
Slide 18: Normally Open Switches
Normally Open Switches 18
Slide 19: Substation Overview
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Slide 20: The Radial System
The Radial System • Distribution System Connected to Transmission System Through Substations. • Traditionally Built to Operate Radially – Source: Waukesha Transmission System is the Source and Distribution System is the Load. – This is changing as the distribution system is installing sources • Upgr
Slide 21: General Substation Overview
General Substation Overview • There Are Many Different Substation Designs and Vintages. • While Differences Exist, There is Equipment that is Found in Most Substations – Step-Down Transformer – Circuit Breakers – Instrument Transformers – Protective Relays Source: Trench 21
Slide 22: Effects of Distribution Energy
Effects of Distribution Energy • Once the Distribution Ceases to be Radial, Modifications may be required to Support that Shift. • These Modifications will Depend on many factors including: – Magnitude of the Distribution Sources – Substation Configuration – Existing Substation Protection and Contro
Slide 23: Common Modifications
Common Modifications • Voltage Supervised Reclosing (VSR) – Related to distribution sources on a feeder level. – Requires modern protective relaying and voltage transformer • Transfer-Trip – Related to generation to load ratio and types of distribution sources – Requires modern protective relaying a
Slide 24: Common Modifications
Common Modifications • Ground Fault Over Voltage Protection (GFOV) or 3V0 – Related to distribution sources at an aggregated substation level – Requires modern protective relaying and high-side voltage transformers Source: Pterra and NY State 24
Slide 25: Solar Rewards Community – Metering
SOLAR REWARDS COMMUNITY – METERING
Slide 26: Secondary Service
Secondary Service • PV system size – 2.25 MW AC or less. • Xcel Energy Standard for Electric Installation and Use manual. – Current revision – November 15, 2018 – Web Link for notification sign up and PDF – https://www.xcelenergy.com/working_with_us/builders/installation_standards • PSCo service vol
Slide 27: Secondary Service – Cont.
Secondary Service – Cont. • Key requirements for one-lines: – Identify conductor size and number of runs to transformer. – Requires metering for both main billing and PV production. • Transformer rated metering – Section 4.10.7 & 4.12 – CT orientation for main billing – utility transformer as source
Slide 28: Primary Service
Primary Service • PV system size – 2.25 MW AC and above (5 MW DC Max) • Requires metering for both main billing and PV production at primary voltage. – No secondary voltage production metering allowed. • Typical voltages – 12.47KV, 13.2KV, 13.8KV, and 24.9KV • Customer owned/maintained secondary dis
Slide 29: Primary Service – PSCo Owned
Primary Service – PSCo Owned • Main billing metering: – Shall be located on the customer’s property within a distance of 5 - 25 feet from the access point. – OH installations to comply with drawing PM-10. – UG installations to comply with drawing PM-40. • Cabinet ratings - 15KV 200A & 600A, 25KV 200
Slide 30: Primary Service – PSCo Owned
Primary Service – PSCo Owned • PV production metering: – Will only be offered for OH services. – Allowed to be located within SRC property, no limitation on distance. – PSCo will provide cluster rack with metering transformers. – Customer to install rack in accordance with drawing PM-10. 30
Slide 31: Primary Service – Customer Owned
Primary Service – Customer Owned • Main billing metering: – Cabinet shall meet PSCo specifications – No exceptions. – Switchgear shall be designed to meet the PSCo specifications for the required utility metering bay. • Manufacture drawings and wiring diagrams require Meter Engineering approval prio
Slide 32: Primary Service – Customer Owned
Primary Service – Customer Owned • PV production metering: – Cabinet may be designed to meet PSCo primary metering cabinet specifications to simplify the approval process. – Other cabinet manufactures permitted. Drawings require written approval in advance of equipment purchase and construction. – S
Slide 33: Primary Metering - Key Points
Primary Metering - Key Points • Key requirements for one-lines: – Identify equipment ownership. – Primary meter installations - Section 4.13 – Meter socket identification – Section 4.14.4 • Meter Engineering approval of equipment is mandatory. • Metering transformers will not be ordered until equipm
Slide 34: Metering Questions?
Metering Questions? 34
Slide 35: Open Phase Testing and Ground Referencing
Open Phase Testing and Ground Referencing
Slide 36: Agenda
Agenda • Open Phase Testing – Background – Requirements – Creating an Open Phase • Ground Referencing 36
Slide 37: Open Phase Testing
Open Phase Testing
Slide 38: Background
Background - Open phase conditions not uncommon - Increased risk to customer equipment - Exposure to live downed conductors 38
Slide 39: Background
Background • Interconnection standards require open-phase response – IEEE 1547 – NEC • Non-Compliance commonly observed – Customer equipment damage 39
Slide 40: Non-Compliance Observations
Non-Compliance Observations Types of Failures Number of Failures 5 Min Tested Passed Failed Delay for Cease Gen High Restart in 2 Sec Voltage # of Sites 90 66 24 # of sites 3 16 3 Total 100% 73% 26% % 12.5% 75% 12.5% Data last updated January 2019 40
Slide 41: Testing Requirements
Testing Requirements • Must Cease Output on all 3-phases within 2 seconds • DER must not exceed 110% voltage on any phase during test • Must delay 5 minutes when source restored 41
Slide 42: Testing Requirements
Testing Requirements • DER must be able to sense and respond to an open phase upstream of the ground bank Area an open phase must be detected Production House Meter Revenue Load Secondary Primary (if applicable) Meter Voltage Voltage Customer Xcel Side Side Ground Bank
Slide 43: Creating an Open-Phase
Creating an Open-Phase • Methods are proposed by developers/installers • Operator is responsible to ensure procedure is designed to NEC/OSHA/other safety considerations • Xcel reviews and approves for technical feasibility – Regardless, onsite, if unsafe, Xcel will use stop-work authority
Slide 44: Ground Referencing
Ground Referencing
Slide 45: Ground Referencing
Ground Referencing • Ground referencing equipment required on all DER ≥100 kW • Refer to Xcel Energy Interconnection Guidelines for specific requirements
Slide 46: Ground Referencing
Ground Referencing • Ongoing evaluation of new industry research • Notable issues: – Line to line connected loads – Frequently dynamic system configurations – High generation to load ratios 46
Slide 47: Overall Program Timeline and General Program Changes/Updates
Overall Program Timeline and General Program Changes/Updates
Slide 48: SRC Process Timeline
SRC Process Timeline ergy ion Item ‘Submit post award requirements (90 calendar days) Perform initial engineering review (15 business days) Prepare good faith estimate (15 business days) Pay good faith estimate (30 business days) Conduct formal study and prepare IA (60 business days) Execute and pay
Slide 49: Program Subscriber Operations Updates
Program Subscriber Operations Updates • Dynamic Reporting Coming • Future RFP subscriber rules • New Customer requirements (3,199kWh or less) • Data Request Form Updates • Telemetry cost update 49
Slide 50: Xcel Energy
(2) Xcel Energy’
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