2020 Customer Irrigation Meeting February 27, 2020 Plymouth Community Center
• Norris Overview, Irrigation Data & Rates • Safety • Power Factor & Capacitors Agenda • Load Management • Data Analytics • EnergyWise Incentives
Norris Overview, Irrigation Data & Rates Bruce Vitosh, General Manager
• 53 Communities • 3,700 Square Miles • 6,150 Miles of Line • 12 Directors • 88 Employees Service Territory
2019 Total Revenues: $85,592,873
2019 Total Use of Revenues: $85,592,873
Facts & Figures: 1,014,456,765 $84,350,862 kWh Sold Operating Revenues 2019 Statistics $9,314,604 $36,314,951 Unrestricted Cash & Capital Expenditures Investments
2014 No Rate Change 2015 No Rate Change 2016 No Rate Change 2017 No Rate Change Norris 2018 0.8% Rate Decrease Customer 2019 0.3% Rate Decrease Rates 2020 0.4% Rate Decrease + 4.5% Production Cost Adjustment (PCA) Credit (February 2020 – January 2021)
Questions? Bruce Vitosh, General Manager
Safety Trevor Wehrer, Manager of Operations
55 • 22 Broken Poles: 7 Farm Equipment Public Liability • 15 Equipment in Overhead Lines: 10 Farm Equipment Reports • 1 Encountered Underground Cable While Digging: (2019) Customer Did Not Call 8-1-1 • 5 Damaged Poles • 4 Pad-Mounted Transformers Hit
SAFETY is the District’s #1 Priority! In 2019, 8 Hotline Trailer Demonstrations Were Conducted.
Do You Know? What should you do if your car or farm equipment comes into contact with electric infrastructure and wires fall on top of your vehicle?
Do You Know? What should you do if your vehicle is on fire or another dangerous situation occurs and you must exit the vehicle that is in contact with power lines?
Questions? Trevor Wehrer, Manager of Operations
Power Factor & Capacitors Jerry Enns, Manager of Engineering
• Existing Legacy Norris customers shall install a secondary capacitor. If no capacitor is installed, a 10% penalty will be assessed, unless the power factor is greater Norris than 93%. Rate • Beginning in 2022, if power factor is not corrected to a minimum of 93%, a billing Schedule demand penalty will be assessed based on the actual power factor as a percent from 93% (pending Board approval) rather than a 10% penalty.
Power Factor Adjustment Examples • Average irrigation well motor at Norris is 60 horsepower, which is equivalent to 45 kW. • For Rate Schedule 13 – Anytime Interruptible, the annual demand charge is $1,071. Actual Power Calculation Increase In Demand Factor Charge 92 45 kW x 93 / 92 $11.64 90 45 kW x 93 / 90 $35.70 85 45 kW x 93 / 85 $100.80 80 16.25% cap at 10% $107.10
For Irrigation Customers : • Voltage Improvement at the Well Motor • Lower Current at Well Motor – Extends Motor Life Benefits of • Lower Current on Irrigation Customer’s Secondary Wiring – Fewer Losses Power Factor For Irrigation Customers and Norris PPD: Correction • Avoids Nebraska Public Power District’s Power Factor Billing Penalty • Allows Increased Load Carrying Capabilities of Existing Equipment • Reduces Electrical Losses from Generator to Irrigation System • Extends Equipment Life due to Lower Current Levels
20 HP & 5 KVAR $605 75 HP & 17.5 KVAR $780 Estimated Capacitor 100 HP & 30 KVAR $935 Installed Cost Capacitor Cost Range: $130 to $560
https://myelectrical.com/tools/power- factor-correction-calculator Power Factor Correction Calculator
https://www.rapidtables.com/calc/electric /power-factor-calculator.html Power Factor Correction Calculator
Power Factor Triangle
• Power Factor (P .F. or PF) = ratio of real power (W) to apparent power (VA) as a percentage. What is • Nameplate provides the power factor for the motor at full load. Power Factor? • Norris must have electric facilities available to meet the full load. • Power factor is improved by adding capacitors.
Questions? Jerry Enns, Manager of Engineering
Norris Meters Jerry Enns, Manager of Engineering
Test Segment Screen
kWh Screen
Max KW Demand
Last Interval KW Demand
PF at Time of Max Demand Interval
Last Interval Power Factor
Questions? Jerry Enns, Manager of Engineering
Load Management Dave Brauning, Manager of Network & Information Systems
Text Messages Control hours from 9:00 a.m. Load to 11:00 p.m. Management Moving Pivots While Under Control Personnel On-Call 24-7
Yukon: AMI Data • Identify Infrastructure Problems Collection • Monitor System Load and Meter Data Trends • Identify Isolated Service Issues
Hourly Usage: Meter is not showing load between 3:00 p.m. and 6:00 p.m. due to load control. If graph shows load between 3:00 p.m. and 6:00 p.m., a service order will be issued to check the controller.
• View Monthly, Daily and Hourly Usage Meter Data Management System (MDMS ) • Perform Rate Studies • Ability to Identify Potential Under or Oversized Transformers • System Voltage Analysis • Line Loss Analysis
Questions? Dave Brauning, Manager of Network & Information Systems
Load Management Ron Thompson, Energy Manager, Nebraska Public Power District
Load Management Norris Public Power District February 27, 2020
2020 Load Management • Billable Demand and Transmission Emergency Relief Messages Programs (TERM) the same as 2019 • Have 11 Billable Demand Groups – Balance out Groups – Group G – Nucor (Nucor is currently in another Rate for NPPD) • Potential billable hours (Mon.-Sat. only): − Summer: 09:01 a.m. to 11:00 p.m. − Maximum of 12 hour continuous hours per day − Maximum of 72 hours per week (Sunday to Saturday) − June 1 st to Sept 15 th − Sundays and 4 th of July can have up to 6 hours of Billable Hours − Labor Day is exempt (Waived all day) 42
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Demand Waiver Process Review NPPD undertook a process review in 2018 effort for the Demand Waiver Program (DWP) with changes to be implemented for the summer of 2018 Review of procedure for calculating load control thresholds and criteria for determining when to declare billable hours Process has not been reviewed in detail in recent years, yet changes have occurred: 2014 - Start-up of SPP Market 2018 - New Large Customer Interruptible Rate (IR) provides an additional tool to manage loads 44
Demand Waiver Process Review - Objectives Development of a documented, written process for when to declare billable hours Development of a near real-time process to estimate summer production demand billing units (and thus revenue recovery) Compare such estimates to budgeted revenues for use in making future decisions for declaring billable hours Establishment of a methodology to set load control thresholds and targets based on resource adequacy and budgeted billable peaks, as opposed to access to WAPA peaking energy 45
Demand Waiver Process Review – Expected Outcomes Potential higher initial load control threshold based on resource adequacy Threshold to exclude customer load on the interruptible rate Increased focus on (and daily estimation of) recovery of budgeted summer demand revenues Once achieved, a higher load control target may be established for the remainder of the season Potential reduction in the number of billable hours 46
New Terminology “Control Threshold”: The load level at which NPPD would start declaring billable hours under the Demand Waiver Program Initial value for summer 2020 is being determined “Target Level”: The load level that NPPD would aim to keep the load at or below during billable hours Initial value for summer 2020 is being determined In prior years, these values were the same, as there was only one threshold based on access to WAPA Peaking Energy Both amounts above exclude customer load on the Interruptible Rate and the loads of those customers that have begun reducing their purchases from NPPD * Initial values may be reduced during the season to facilitate collection of budgeted demand revenues 47
Declaring Billable Hours – Pre 2019 Procedure Load (MW) Projectedload without load management Sunday or July 4th 200 MW Threshold Mon-Sat Declare billable hours for groups as necessary to stay below these levels Eligible Billable Hours 48 Hours of the Day
Declaring Billable Hours Before Achieving Budgeted Demand Billing Units – New Procedure Load (MW) Projected load without load management Sunday or July 4th Control 2,783 MW Threshold Target 2,527 MW Level Mon-Sat Declare billable hours for groups as necessary to stay below these levels Eligible Billable Hours 49 Hours of the Day
Declaring Billable Hours After Achieving Budgeted Demand Billing Units – New Procedure Load (MW) Projected load without load management Control Threshold 2,783 MW * & Target ( * Or, if greater, Level the highest anytime peak load Declare billable hours for that has occurred groups as necessary to this season) stay below this level Eligible Billable Hours 50 Hours of the Day
Results of the 2019 Summer Season 51
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