2020 Customer Irrigation Meeting February 27, 2020 Plymouth - - PowerPoint PPT Presentation

2020 Customer Irrigation Meeting

February 27, 2020 Plymouth Community Center

Agenda

• Norris Overview, Irrigation Data

& Rates

• Safety
• Power Factor & Capacitors
• Load Management
• Data Analytics
• EnergyWise Incentives

Norris Overview, Irrigation Data & Rates

Bruce Vitosh, General Manager

Service Territory

• 53 Communities
• 3,700 Square Miles
• 6,150 Miles of Line
• 12

Directors

• 88

Employees

2019 Total Revenues: $85,592,873

2019 Total Use of Revenues: $85,592,873

Facts & Figures: 2019 Statistics

1,014,456,765

kWh Sold

$84,350,862

Operating Revenues

$36,314,951

Unrestricted Cash & Investments

$9,314,604

Capital Expenditures

Norris Customer Rates

2014 No Rate Change 2015 No Rate Change 2016 No Rate Change 2017 No Rate Change 2018 0.8% Rate Decrease 2019 0.3% Rate Decrease 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 Public Liability Reports

(2019)

• 22 Broken Poles:

7 Farm Equipment

• 15 Equipment in Overhead Lines:

10 Farm Equipment

• 1 Encountered Underground Cable While Digging:

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

Norris Rate Schedule

• 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 than 93%.

• Beginning in 2022, if power factor is not

corrected to a minimum of 93%, a billing 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 Factor Calculation Increase In Demand 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

Benefits of Power Factor Correction

For Irrigation Customers:

• Voltage Improvement at the Well Motor
• Lower Current at Well Motor – Extends Motor Life
• Lower Current on Irrigation Customer’s Secondary

Wiring – Fewer Losses

For Irrigation Customers and Norris PPD:

• 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

Estimated Capacitor Installed Cost

20 HP & 5 KVAR $605 75 HP & 17.5 KVAR $780 100 HP & 30 KVAR $935 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

What is Power Factor?

• Power Factor (P

.F. or PF) = ratio of real power (W) to apparent power (VA) as a percentage.

• Nameplate provides the power factor for the

motor at full load.

• 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

Load Management

Text Messages

Control hours from 9:00 a.m. to 11:00 p.m.

Moving Pivots While Under Control Personnel On-Call 24-7

Yukon: AMI Data Collection

• Identify Infrastructure Problems
• 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.

Meter Data Management System (MDMS)

• View Monthly, Daily and Hourly Usage
• 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

• 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 1st to Sept 15th −Sundays and 4th of July can have up to 6 hours of Billable Hours −Labor Day is exempt (Waived all day)

42

2020 Load Management

43

Demand Waiver Process Review

44

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

Demand Waiver Process Review - Objectives

45 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

Demand Waiver Process Review – Expected Outcomes

46

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

New Terminology

47

“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

Declaring Billable Hours – Pre 2019 Procedure

48

Load (MW) Hours of the Day Threshold

Mon-Sat Sunday or July 4th

Projectedload without load management Eligible Billable Hours Declare billable hours for groups as necessary to stay below these levels 200 MW

Declaring Billable Hours Before Achieving Budgeted Demand Billing Units – New Procedure

49

Load (MW) 2,783 MW 2,527 MW Hours of the Day Control Threshold Target Level

Mon-Sat Sunday or July 4th

Projected load without load management Eligible Billable Hours Declare billable hours for groups as necessary to stay below these levels

Declaring Billable Hours After Achieving Budgeted Demand Billing Units – New Procedure

50

Load (MW) 2,783 MW * Hours of the Day Control Threshold & Target Level

(* Or, if greater, the highest anytime peak load that has occurred this season) Projected load without load management Eligible Billable Hours Declare billable hours for groups as necessary to stay below this level

51 Results of the 2019 Summer Season

Summer mmer 2019 19 Res esul ults ts

52

52

Another wet and mild summer! Did not see normal irrigation load levels. Never reached initial Control Threshold. Initial threshold values were reduced on July 16th to facilitate collection of budgeted demand revenues Then-current thresholds were reduced again on August 20th

At that time, the four (4) highest billable loads on separate days were: 2,258, 2,196, 1,989 and 1,955 for an average of 2,100 MW To improve the average by 50 MW, would require increasing the 4th highest by 200 MW, i.e. target of 2,155 MW

2019 Control Target Highest Highest Effective Threshold Level Billable* Anytime Dates (MW) (MW) Peak (MW) Peak (MW) (A) (B) (C) (D) (E) 6/1 - 7/15 2,707 2,458 N/A 2,318 7/16 - 8/19 2,500 2,250 2,258 2,505 8/20 - end 2,400 2,150 N/A 2,123 * With all groups having billable hours simultaneously Note: All load values below exclude customers on interruptible rate and customers who have begun reducing their purchases from NPPD.

Summer 2019 Results (cont’d.)

53

53

18 23 22 44 29 16 27 32 23 8 4 10 20 30 40 50 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019

Total Billable Days

In 2018 & 2019, no control group had more than 4 billable hours in a day

Summer 2019 Results (cont’d.)

54

54

61 134 150 370 210 91 119 184 133 26 16 50 100 150 200 250 300 350 400 2009 2010 2011 2012 2013 2014 2015 2016 2017 2018 2019

Total Billable Hours

In 2018 & 2019, no control group had more than 4 billable hours in a day

55 2020 Spring and Summer Projections

Accuweather Spring Forecast

56

Latest Drought Monitor

57

58

Frontier Weather Report 59

Other Impactors

60

• Moisture in other

areas

• Time of Year

(moisture needs)

• School Load in

August

• Non- Ag Industries

Questions?

Ron Thompson, Energy Manager, Nebraska Public Power District

EnergyWise Incentives

Cory Fuehrer, Energy Efficiency Program Manager, Nebraska Public Power District

Prescriptive Irrigation Program

Corner Pivot (VFD) Variable Frequency Drive Program

Custom Irrigation Efficiency Program

Questions?

Cory Fuehrer, Energy Efficiency Program Manager, Nebraska Public Power District