MINUTES OF A REGULAR MEETING OF THE BOARD OF ......Ryan Mooney Kate Hutchinson Stephanie O’Connor...

MINUTES OF A REGULAR MEETING AND RETREAT OF THE BOARD OF PUBLIC UTILITIES OF

THE CITY OF SPRINGFIELD, MISSOURI

The Regular Meeting and Retreat of the Board of Public Utilities of the City of Springfield, Missouri (“Board”), was held on Thursday, October 29, 2020, at Noon. (Notice and Tentative Agenda of Meeting attached.)

Board members present:

Scott Bratcher Kristin Carter Louise Knauer Rob Rector Joe Reynolds Lynn Rowe Denise Silvey (virtual) Nancy Williams Jennifer Wilson Don Woody

Board members absent:

Mark Millsap

Ex-Officio Board member present:

Jason Gage

constituting a majority of the Board and a quorum.

In addition to the Board members listed as present above, the following persons were present for the meeting:

Joel Alexander Brent Baker Matt Crawford Amy Derdall Dwayne Fulk Gary Gibson Kate Hutchinson Chris Jones Kelly Laurie Jerrod McCully Brent McKinney Stephanie O’Connor Jeff Parkison Jamie Presley Steve Stodden Dean Thompson Renee Vines

2a

2

Mr. Rob Rector, Acting Chair of the Board, presided and called the meeting to order.

1. A video message from Mr. John Twitty, President & CEO of Missouri Public Utility Alliance (MPUA), was shown. He congratulated Mr. Brent McKinney, retiring Director – Electric Transmission & Distribution, for being selected as the recipient of MPUA’s Paul Jensen Individual Achievement Award, and announced that the MPUA Board approved a resolution honoring Mr. McKinney for his service to City Utilities, the State of Missouri, and the United States. Mr. Gary Gibson, General Manager, introduced Mr. McKinney and recognized him for these prestigious achievements.

2. Next, Chair Rector stated that if there was no objection, Minutes of the Regular

Board Meeting held September 24, 2020, Item 2a, were approved; there was none. 3. The next order of business to come before the meeting was public comment; there

was none. 4. The next order of business to come before the meeting was Committee Reports by

Committee Chairs; there were none. 5. Ms. Amy Derdall, Associate General Manager – Chief Financial Officer, and Mr.

Jeff Parkison, Director – Forecasting & Power Marketing, gave a presentation on the September 2020 Board financials, and presented Item 5a, Financial Statements with supporting documents for the year-to-date through September 30, 2020, for Board consideration as follows:

Meeting of the Board of Public Utilities

October 29, 2020

Pre GASB 68 Adjustment

Heating/Cooling Degree Days(HDD/CDD)

(1,250)

(1,000)

(750)

(500)

(250)

0

250

500

Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep

HDD CDD Normal

HDD = Avg. temp <65º CDD = Avg. temp >65º

3

4

PrecipitationReported in Inches

0

2

4

6

8

10

12

14

Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sept

Actual Normal

Market Benefit

$144

$552$478

$239

$25$139 $131

$0

$543

$154

$357$437 $423

0

0.5

1

1.5

2

2.5

- $150

$100

$350

$600

$850

$1,100

$1,350

$1,600

Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sep

Net Market Benefit Avg Nat Gas Price

Thousands of DollarsMarket Benefit

Avg Nat Gas Price

5

6

CU Generation & PPA Mix

Coal-Self6.3%

Coal-Market49.8%

Natural Gas6.4%

Noble Hill0.3%

Wind32.8%

Hydro4.1%

Solar0.3%

September

Coal-Self5.7%

Coal-Market44.3%

Natural Gas6.2%

Noble Hill0.5%

Wind36.9%

Hydro6.1%

Solar0.2%

FY 2020

Operating RevenueMillions of Dollars

$474.1$442.4

$468.4

FY 2019 FY 2020 Budget $56.7

$16.2

$0.8

$81.5

$287.2

$54.9

$17.9

$1.1

$93.5

$301.1

Water

SpringNet/TRS

Transit

NaturalGas

Electric

Budget

Fiscal Years to Date Through September 30

7

8

Operating ExpenseMillions of Dollars

$406.5$378.7

$416.4

FY 2019 FY 2020 Budget$64.6

$49.1

$34.4

$38.9

$37.8

$18.6

$135.2

$66.0

$46.7

$38.7

$44.4

$41.3

$22.1

$157.0

Depreciation

Maintenance

A&G

OtherOperatingExpense

Distribution &Transmission

OtherProduction

Prod Fuel,Purch Pwr,Purch Gas

Budget


Operating Income (Loss)Millions of Dollars

$67.6$63.7

$52.0

FY 2019 FY 2020 Budget$18.9

$3.7

-$11.2

$7.4

$44.8

$13.1

$3.5

-$11.8

$8.9

$38.3

Water

SpringNet/TRS

Natural Gas

Electric

Budget

Transit


9

10

Change in Net Position, excl. MVAMillions of Dollars

$68.2

$55.5 $55.2

$42.5$46.2

FY 2018 FY 2019 FY 2020 Budget FY 2015-2019Average


Accounts ReceivableSeptember

Millions of Dollars

$14.6$11.3

$3.3

$10.0

$9.5

$0.5

$24.6

$28.2

$20.8

$24.2

$3.8 $4.0

C&I

Res

FY 2020 BudgetTotal

5-Year Max

Current ArrearsFY 2020 Budget FY 2020 Budget

11

12

Accounts Receivable ArrearsMillions of Dollars

$2

$3

$4

$5

$6

$7


FY 2019 FY 2020 Budget

Investment in CoalThousands of DTH and Millions of Dollars

131

284

182163

$4.1

$9.1

$5.8$5.2

Tons Cost

$31.13/Ton

FY 2018

$32.01/Ton

FY 2019

$31.56/Ton $31.75/Ton

FY 2020 Actual

FY 2020 Budget

September

13

14

Investment in Natural GasThousands of DTH and Millions of Dollars

2,011 2,022

2,244 2,309$5.0

$4.0 $3.8

$5.4

DTH Cost

$2.49/DTH

FY 2018

$1.99/DTH

FY 2019

$1.68/DTH $2.36/DTH

FY 2020 Actual

FY 2020 Budget

SeptemberMaximum Storage Capacity is ~2.4M Dth

Natural Gas Prices per DTH

$0.00

$1.00

$2.00

$3.00

$4.00

$5.00


Budget 2020 FY 2019 FY 2020

15

16

Fiber Expansion Project

ProjectBudget

ActualProject Remaining

Design & Construction Management $ 16.3 $ 10.2 $ 6.1

Make Ready Distribution 24.4 16.7 7.7Aerial & Underground Construction 95.0 18.8 76.2

Backbone Construction 3.6 8.8 (5.2)

Hut Construction 2.2 1.4 0.8

Total $ 141.5 $ 55.9 $ 85.5

Millions of Dollars

Make Ready

Fiber Construction

Norton 100% 100%

Nichols 100% 10%

Glenstone 86% 0%

Kansas 26% 0%

Twin Oaks 0% 0%

Clay 0% 0%

Sunset 0% 0%

Completion by Hut

Target Range

Days Cash By Month excl. MVADaily Cash Requirement $960,000

40

60

80

100

120

140

160

Oct Nov Dec Jan Feb Mar Apr May Jun Jul Aug Sept

Actual Budget High Low

Days

17

18

$0

$25

$50

$75

$100

Actual Budget

Operating Earnings

Operating Requirement

$ 89.0 $ 84.1

$ 89.4 $ 93.7

Earnings Less Requirement $ (0.4) $ (9.6)

Electric Operating Earnings & Cash(Millions)

Actual Compared to Budget

Revenue ↓ $ 13.9 5%

Expense ↓ $ 20.4 8%

Capital ↓ $ 5.3 14%

$0

$5

$10

$15

$20

Actual Budget

Operating Earnings


$ 14.3 $ 15.7

$ 16.8 $ 14.1

Earnings Less Requirement $ (2.4) $ 1.7

Natural Gas Operating Earnings & Cash


Revenue ↓ $ 12.0 13%

Expense ↓ $ 10.5 12%

Capital ↑ $ 3.1 25%

(Millions)

19

20

$0

$5

$10

$15

$20

$25

$30

Actual Budget

Operating Earnings


$ 26.3 $ 20.2

$ 18.9 $ 20.1

Earnings Less Requirement $ 7.4 $ 0.1

Water Operating Earnings & Cash


Revenue ↑ $ 1.8 3%

Expense ↓ $ 4.0 10%

Capital ↓ $ 1.2 7%

(Millions)

$0

$2

$4

$6

$8

$10

Actual Budget

Operating Earnings

Operating Requirement*

$ 6.2 $ 6.3

$ 8.5 $ 7.0

Earnings Less Requirement $ (2.3) $ (0.7)

SpringNet Operating Earnings & Cash


Revenue ↓ $ 1.6 10%

Expense ↓ $ 1.5 12%

Capital ↑ $ 21.7 58%

* Includes FY 2021 financing proceeds for September 2020 capital spending and accrual

(Millions)

21

22

Community ServicesFYTD September 30 , 2020

Thousands of DollarsCity of Springfield

Cash Payments in Lieu of Taxes $14,143Right of Way Fee 536Utility Services 12,520Public Transit Services 6,014Relocations and Other Community Services 2,463Total City of Springfield $35,675Other Services to Community 443Total Community Services $36,118

8.2%TargetRange:7% - 8%

23

City Utilities of Springfield

Board of Public Utilities

Financial Statements and Additional Information

September 30, 2020

Pre GASB68 Unaudited

5a

City Utilities of Springfield, Missouri

Board of Public Utilities

Financial Statements and Additional Information

September 30, 2020

Description Page

Financial Key Indicators 1-2

Financial Statements:

Statements of Net Position 3-4

Statements of Revenues, Expenses and Changes in Net Position 5-6

Statements of Cash Flows 7

Summary of Fund Receipts and Disbursements 8

Notes to Financial Statements 9-16

Additional Information:

Summary of Revenues and Other Billings 17

Summary of Disbursements 18

Total Company Summary of Expenditures by Category 19

Budget Changes by Category 20

Approved Transfers and Reclassifications 21

Accounts Receivable - Aging 22-23

Summary of TEA Transactions 24

Professional Services Contracts 25

Net Market Benefit 26

i

10/23/2020 11:26 AM

Line Over (Under)Notes No. Actual Budget

1 FUND BALANCES 2 Working Capital3 Operating Fund $ 40,551 $ 6,5514 Working Capital - Other 84,461 16,7055 Total Working Capital 125,012 23,2566 Bond Funds 6,422 07 Construction Fund 0 0

* 8 Designated Improvement Account (Note 1) 148,242 16,801* 9 Total City Utilities Fund Balances (Note 8) 279,676 40,057

10 DAYS CASH 119 13

11 ACCOUNTS RECEIVABLE12 Total Current $ 22,875 $ (1,340)13 Total Delinquent 3,816 (146)14 Allowance for Doubtful Accounts (500) (92)15 Total Accounts Receivable $ 26,191 $ (1,579)

16 COAL INVENTORY:17 Tons 182 2018 Amount $ 5,757 $ 58819 COAL PURCHASES:20 Tons 796 (448)21 Amount $ 26,471 $ (16,682)22 Cost Per Ton (Includes Freight) $ 33.27 $ (1.44)

23 NATURAL GAS INVENTORY:24 DTH 2,244 (65)25 Amount $ 3,780 $ (1,664)26 Avg Cost Per DTH $ 1.68 $ (0.68)27 NATURAL GAS TOTAL PURCHASES28 DTH 14,910 (743)29 Purchased Gas Amount $ 27,051 $ (13,869)30 Purchased Gas Transmission Amount 12,353 76231 Total 39,404 (13,107)32 Cost Per DTH $ 2.64 $ (0.71)

($, Tons and DTH In Thousands)

City Utilities of Springfield, MissouriBoard of Public Utilities Financial Statements

Summary of Financial Reports - "Key Indicators" (Note 3)Year to Date Through September 30, 2020

* See Accompanying Notes To Financial Statements May not add due to rounding. Page 1

10/23/2020 11:26 AM


($, Tons and DTH In Thousands)


Summary of Financial Reports - "Key Indicators" (Note 3)Year to Date Through September 30, 2020

1 LABOR:2 Regular $ 76,377 $ (2,636)3 Overtime 5,683 2854 Total $ 82,060 $ (2,351)5 Number of Employees: (End of Month)6 Full Time 941 (12)7 Part Time 24 (4)8 Total 965 (16)

9 TOTAL REVENUES AND OTHER BILLINGS $ 558,876 $ (19,783)

10 TOTAL EXPENDITURES 11 Fuels $ 123,629 $ (18,939)12 Non-Capital 304,860 (25,881)13 Capital 112,888 (15,721)14 Total $ 541,377 $ (60,541)

15 CHANGE IN NET POSITION (EQUITY) 60,353 17,859

16 FUEL ADJUSTMENT (OVER)/UNDER RECOVERY* 17 Electric (Note 2) $ (7,271) $ (6,290)* 18 Natural Gas (Note 2) $ 931 $ 844

(Over) recovery represents liability yet to be refunded.Under recovery represents receivable yet to be billed.

* See Accompanying Notes To Financial Statements May not add due to rounding. Page 2

10/16/2020 9:36 AM


1 Utility Plant, At Cost:2 Plant In Service $ 2,436,625 $ 46,9543 Less Accumulated Depreciation 986,617 29,0354 Net Plant In Service 1,450,007 17,9195 Construction Work In Progress 88,111 (21,819)6 Net Utility Plant 1,538,118 (3,900)7 Funds For Bonded Indebtedness 6,422 08 Construction Funds 0 09 Equity Fund - JTEC 0 0

* 10 Designated Improvement Account (Note 1) 148,242 16,80111 Working Capital - Other 84,461 16,705

* 12 Price Risk Management Assets (Note 12) (110) 2,958* 13 Equity Interest In Partnership Industrial Center (Note 7) 1,886 (128)* 14 Equity Interest In Prepaid Gas Services (Note 15) 90 90* 15 Equity Interest In The Energy Authority (Note 9) 2,973 (9,211)* 16 Regulatory Assets - Asset Retirement Obligations (Note 16) 1,618 145

17 Other Noncurrent Assets 10,871 (154)18 Total Noncurrent Assets 1,794,571 23,30619 Current Assets:20 Cash And Cash Equivalents 40,551 6,551

* 21 Short-term Investments - (Note 8) 0 022 Less: Noncurrent Maturities 0 0

23 Cash, Cash Equivalents And Short-term Investments 40,551 6,55124 Accounts Receivable:25 Customers, Less Allowance For Doubtful Accounts Of $500 26,191 (1,579)26 Unbilled Revenues 13,865 (2,353)27 Other 3,887 3,06928 Fuel Adjustments And Natural Gas Refunds29 Inventories:30 Materials And Supplies 35,834 9,75031 Coal 5,757 58832 EPA Emissions Allowances 0 0

33 Natural Gas 3,780 (1,664) 34 Emission Consumables 127 21 35 Prepayments 1,782 133

36 Total Current Assets 131,774 14,515* 37 Deferred Outflows of Resources (Note 13)

38 Unamortized Loss on Reacquired Debt 14,219 039 GASB 68 Expected Vs. Actual Experience 14,124 040 Total Deferred Outflows of Resources 28,344 041 Total Assets and Deferred Outflows $ 1,954,689 $ 37,821

($ in Thousands)


Statements of Net Position (Note 3)September 30, 2020

* See Accompanying Notes to Financial Statements May not add due to rounding.

Page 3

10/16/2020 9:36 AM


1 Net Position (Equity) $ 1,263,212 $ 17,859

2 Long-term Obligations:* 3 Total Long-term Obligations Outstanding (Note 5) 494,747 4,447

4 Unamortized Premium (Discount) 34,114 0

5 Total Long-term Obligations 528,860 4,447

* 6 Asset Retirement Obligations (Note 16) 1,618 145

* 7 Price Risk Management Liabilities (Note 12) 0 0

* 8 Net Pension Liability (Note 14) 17,957 0

9 Other Noncurrent Liabilities 19,021 (3,901)

10 Total Noncurrent Liabilities 567,456 691

11 Current Liabilities:* 12 Current Portion Of Long-term Obligations (Note 5) 34,875 0

13 Accounts Payable:14 Trade 28,920 12,99715 Other 5,917 (1,404)16 Customer Deposits 4,911 3317 Accruals:18 Interest 3,542 (78)19 Salaries And Wages 2,022 (396)20 Payments In Lieu Of Taxes 1,203 (21)

* 21 Fuel Adjustments And Natural Gas Refunds (Notes 2 and 12) 5,565 8,93822 Purchased Power 3,043 (400)23 Purchased Fuels 3,333 (661)24 Current Portion of Sick and Vacation 10,603 5125 Other 2,184 211

26 Total Current Liabilities 106,118 19,271

27 Total Net Position and Liabilities 1,936,786 37,821

* 28 Deferred Inflows of Resources (Note 13)29 GASB 68 Expected vs Actual Experience 17,902 030 Total Deferred Inflows of Resources 17,902 031 Total Net Position, Liabilities and Deferred Inflows of Resources $ 1,954,689 $ 37,821


Statements of Net Position (Note 3)September 30, 2020

($ in Thousands)

* See Accompanying Notes to Financial Statements May not add due to rounding.

Page 4

10/16/2020 9:22 AM

Line Over(Under)

Notes No. Actual Budget

1 Operating Revenues: $ 442,402 $ (26,007)

2 Operating Expense:

* 3 Production Fuel And Purchased Power (Note 6) 92,855 (12,772)

* 4 Natural Gas Purchased (Note 12) 42,387 (9,020)

5 Other Production 18,579 (3,505)

6 Distribution And Transmission 37,835 (3,484)

7 Bus And Garage Operations 5,908 (521)

8 Other Services 5,512 (1,809)

9 Customer Accounts 12,558 (3,341)

10 Administrative And General 34,440 (4,302)

11 Maintenance 49,138 2,396

12 Depreciation and Amortization 64,650 (1,335)

* 13 (Gain) Loss On Other Activities (Note 10) (0) (0)

14 Payment In Lieu Of Taxes 14,291 (1)

15 Other Taxes 589 26

16 Total Operating Expense 378,744 (37,669)

17 Operating Income (Loss) 63,659 11,663

18 Other Income (Expense)

19 Interest Income 5,416 (824)

* 20 Net Increase (Decrease) in Fair Market Value of Investments (Note 8) 5,157 5,157

* 21 Gain Or (Loss) On Investments (Note 9) (676) 824

22 Interest Expense (21,966) 225

* 23 Allowance For Funds Used During Construction (Note 4) 1,179 (264)

24 Operation Of Recreational Facilities (251) 148

25 Long-Term Obligations Related Amortization 2,066 39

* 26 Miscellaneous Income (Expense) (Note 11) 5,769 891

27 Total Other Income (Expense) (3,306) 6,196

28 Change in Net Position (Equity) 60,353 17,859

29 Net Position (Equity) At Beginning Of Period 1,202,859 0

30 Net Position (Equity) At End Of Period $ 1,263,212 $ 17,859

($ in Thousands)


Board of Public Utilities Financial Statements

Statements of Revenues, Expenses and Changes in Net Position (Note 3)

Year to Date Through September 30, 2020

* See Accompanying Notes to Financial Statements

May not add due to rounding.

Page 5

10/16/2020 9:22 AM

Line Over(Under) Over(Under) Over(Under) Over(Under) Over(Under) Over(Under)

Notes No. Actual Budget Actual Budget Actual Budget Actual Budget Actual Budget Actual Budget

1 Operating Revenues: $ 287,216 $ (13,869) $ 81,488 $ (12,003) $ 791 $ (265) $ 16,238 $ (1,656) $ 56,669 $ 1,787 $ 442,402 $ (26,007)

2 Operating Expense:

* 3 Production Fuel And Purchased Power (Note 6) 92,855 (12,772) 92,855 (12,772)

* 4 Natural Gas Purchased (Note 12) 42,387 (9,020) 42,387 (9,020)

5 Other Production 11,924 (2,091) 6,655 (1,413) 18,579 (3,505)

6 Distribution And Transmission 24,887 (3,717) 8,320 (246) 4,628 479 37,835 (3,484)

7 Bus And Garage Operations 5,908 (521) 5,908 (521)

8 Other Services 25 25 5,487 (1,834) 5,512 (1,809)

9 Customer Accounts 5,595 (1,477) 3,434 (1,055) 20 (6) 3,509 (803) 12,558 (3,341)

10 Administrative And General 18,975 (3,494) 4,809 (109) 2,049 (54) 2,770 (23) 5,837 (623) 34,440 (4,302)

- Franchise Requirements 6,142 (157) 219 (521) 6,160 (4) 12,520 (682)

- Duplicate Charges - credit (6,142) 157 (219) 521 (6,160) 4 (12,520) 682

11 Maintenance 34,993 4,579 5,151 12 1,509 (148) 7,485 (2,047) 49,138 2,396

12 Depreciation and Amortization 44,145 (1,630) 6,974 119 2,452 (166) 3,706 22 7,374 320 64,650 (1,335)

* 13 (Gain) Loss On Other Activities (Note 10) (0) (0) (0) (0)

14 Payment In Lieu Of Taxes 8,979 147 3,040 (201) 32 (11) 2,241 64 14,291 (1)

15 Other Taxes 10 1 579 25 589 26

16 Total Operating Expense 242,379 (20,431) 74,126 (10,500) 11,949 (899) 12,561 (1,816) 37,729 (4,023) 378,744 (37,669)

17 Operating Income (Loss) $ 44,837 $ 6,561 $ 7,363 $ (1,502) $ (11,158) $ 634 $ 3,676 $ 160 18,941 $ 5,810 63,659 $ 11,663

18 Other Income (Expense)

19 Interest Income 5,416 (824)

* 20 5,157 5,157

* 21 (676) 824

22 Interest Expense (21,966) 225

* 23 337 121 1,179 (264)


25 2,066 39

* 26 Miscellaneous Income (Expense) (Note 11) 421 8 5,113 11 (3) 5,769 891

27 Total Other Income (Expense) (3,306) 6,196

28 Change in Net Position (Equity) 60,353 17,859

29 Net Position (Equity) At Beginning Of Period 1,202,859 0

30 Net Position (Equity) At End Of Period $ 1,263,212 $ 17,859



Statements of Revenues, Expenses, and Changes in Net Position (Note 3)

Year To Date Through September 30, 2020

Allowance For Funds Used During Construction (Note 4)

($ in Thousands)

Long-Term Obligations Related Amortization

Natural GasElectric Water TotalSpringNet/Trunked RadioTransportation

Net Increase (Decrease) In Fair Market Value Of Investments (Note 8)

Gain Or (Loss) On Investments (Note 9)

* See Accompanying Notes To Financial Statements

May not add due to rounding. Page 6

N

O

T

E Line Over (Under)

S No. Actual Budget

1 RECONCILIATION OF NET OPERATING INCOME TO

2 NET CASH PROVIDED BY OPERATING ACTIVITIES:

3 Net Operating Income (Loss) $ 63,659 $ 11,663

4 Adjustments To Reconcile Net Operating Income To

5 Net Cash Provided By Operating Activities:

6 Depreciation Expense 64,650 (1,335)

7 Auto Depreciation Included In Vehicle Expense 2,173 (174)

8 Miscellaneous Income (Expense) 199 99


10 Change In Assets And Liabilities:

11 Accounts Receivable (2,829) (1,490)

12 Unbilled Revenues 2,131 2,353

13 Price Risk Management Assets (2,958) (2,958)

14 Recoverable Fuel Costs 12,470 8,938

15 Inventories (6,522) (8,673)

16 Prepayments (288) (133)

17 Other Noncurrent Assets (2,146) 154

18 Prepaid Pension Assets 0 0

19 Accounts Payable 13,206 11,572

20 Customer Deposits 104 33

21 Accrued Liabilities (1,035) (1,215)

22 GASB 68 Net Pension Liability 0 0

23 Other Noncurrent Liabilities (1,212) (3,951)

24 Net Cash Provided By (Used For) Operating Activities 141,351 15,031

25 CASH FLOWS FROM NONCAPITAL FINANCING ACTIVITIES:

26 Receipts from Federal and State Grants 4,264 1,491

27 CASH FLOWS FROM CAPITAL FINANCING ACTIVITIES:

28 Transfers of Financing proceeds from JTEC Equity Fund 0 0

29 Proceeds from issuance of capital obligations 35,447 4,446

30 Transfer of financing proceeds to construction fund 0 0

31 Debt Issuance Costs 0 0

32 Transfer of financing proceeds from construction fund 0 0

33 Capital Grants And Contributions 8,615 3,894

34 Additions To Utility Plant, Net Of Removal (126,412) 750

35 Repayment of Long-term Obligations (33,205) 0

36 Outside Financing Fees (288) 39

37 Debt Fee 0 0

38 Interest Paid (22,325) (1)

39 Net Cash Provided From (Used For) Capital Financing Activities (138,168) 9,128

40 CASH FLOWS FROM INVESTING ACTIVITIES:

41 Transfers of Financing proceeds from JTEC Equity Fund 0 0

42 Sale And Maturities Of Investment Securities 132,264 102,902

43 Purchase Of Investment Securities (131,729) (131,729)

44 Interest Received 5,895 (345)

45 Arbitrage Payable 0 0

46 Equity Interest in Electric Power Alliance (1,306) 10,037

* 47 Equity Interest in Prepaid Gas Services (Note 15) (90) (90)

* 48 Equity Interest in Partnership Industrial Centers (Note 7) (5) 126

49 Distribution from Partnership Industrial Centers 0 0

50 Net Cash Provided From (Used For) Investing Activities 5,029 (19,099)

51 NET INCREASE (DECREASE) IN CASH AND CASH EQUIVALENTS 12,476 6,551

52 CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD 28,076 0

53 CASH AND CASH EQUIVALENTS AT END OF PERIOD $ 40,552 $ 6,551

54 NONCASH CAPITAL FINANCING ACTIVITIES:

55 Capital assets acquired through contributions from developers. $ 16,728 $ 16,728

56 NONCASH INVESTING ACTIVITIES:

Market Value Adjustment 5,157 5,157



Statements of Cash Flows (Note 3)

Year to Date Through September 30, 2020

($ In Thousands)

See Accompanying Notes to Financial Statements.

May not Add due to rounding. Page 7



Summary of Fund Receipts and Disbursements (Note 3)

September 30, 2020

($ In Thousands)

Line Over (Under)

Notes No. Actual Budget

1 City Utilities - Operating Fund:

2 Receipts $ 537,977 $ (71,492)

3 Disbursements 535,489 (78,043)

4 Excess of Receipts (Disbursements) 2,488 6,551

5 Beginning Balance 38,063 0

6 Ending Balance $ 40,551 $ 6,551

7 Other Funds:

8 Receipts $ 0 $ 0

9 Disbursements (14,131) (33,506)



13 Ending Balance $ 239,125 $ 33,506

14 All Funds:

15 Receipts $ 537,977 $ (71,492)

16 Disbursements 521,358 (111,549)



19 Ending Balance $ 279,676 $ 40,057


May not add due to rounding

Page 8



Notes to the Financial Statements

Note 1 Designated Improvement Account

Key Indicators, Page 1, Line 8

Statements of Net Position, Page 3, Line 10

I. Funds For Electric Clean Air Compliance (A)Restricted Funds $ 0

II. Reserves & Current Funding Requirements (B)Funds Authorized by the Board

Other Reserves

Disaster Recovery (B) $ 23,581,000

Contingency (B) 24,518,000

Pollution Reserve 33,976,000

Trunked Radio System Reserves 1,075,000

Total Funds Required by the Board $ 83,150,000

III.Funds Designated by the CFO

Capital Reserves (A) $ 56,927,000

Fuel Over Recovery 7,271,000

Noble Hill Landfill 895,000

Total Funds Designated by the CFO $ 65,092,000

Balance of Designated Improvement Account $ 148,242,000

Funds transferred to the Designated Improvement Account may be used for the maintenance and repair of, or for construction, acquisitions, extensions and

improvements to the system.

Footnotes to Details:

(A) The balance includes the sale of Clean Air Allowances.

September 30, 2020

(B) Other Reserve Funds were adjusted to comply with the actuarial study approved by the Board June 22, 1995, with an annual review of balances and adjustment for

inflation. Funds received as compensation to modify insurance coverage under certain policies have been placed in this reserve. The consultants further recommended

that exposure levels be re-evaluated every 10 years and the reserve funds adjusted to recognize the most current identified exposure levels. The study was updated

during Fiscal 2006 and the funds were reallocated as part of the 2007 Annual Budget approval. The latest update performed in 2011 revealed that exposure coverage for

the Disaster Recovery and Contingency funds had dropped to 57% of identified exposures. The committee suggested and Management approved adopting a minimum

target of 66% coverage to be attained over a 10 year horizon.

The Designated Improvement Account includes $1,250,000 of securities pledged to the Division of Worker's Compensation, State of Missouri, as a security deposit of self

insurance.

May not add due to roundingPage 9

Note 2 Electric Fuel And Natural Gas Cost Recovery

Key Indicators, Page 2, Lines No. 17 and 18

Statements of Net Position, Page 3, Line No. 27 or Page 4, Line No. 21

Note 3 Budget Adjustments

General

All Financial Statements

Note 4 Allowance For Funds Used During Construction

Statements of Revenues, Expenses and Changes in Net Position, Pages 5 and 6, Line No. 23




September 30, 2020

The electric fuel and natural gas cost adjustment (over)/under recovery amounts reflect the difference between actual fuel expenditures and amounts collected through base rates for fuels, increased or decreased for the

adjustment factors.

The electric fuel recovery amount represents the difference between actual fuel costs and amounts collected for fuels on a cumulative basis since October, 1981. The current fuel adjustment rate per kilowatt hour is a credit of

$.0162. The fuel adjustment rate for October 2019 to March 2020 was a credit of $.0170.

The balance as shown on the Statements of Net Position includes the electric fuel over recovery of $7,271,000, the natural gas cost under recovery of $931,000 and a change in the fair market value of the natural gas hedging

options of $775,000.

The natural gas cost recovery amount represents the difference between actual natural gas costs and amounts collected for fuels on a cumulative basis since October 1, 1993, when CU natural gas rates were restructured under

FERC Order 636. The current natural gas recovery adjustment factor per DTH is a credit of $.406. The natural gas recovery adjustment factor per DTH for October 2019 through March 2020 was a debit of $.098.

Net interest costs related to acquiring or constructing certain utility plant are capitalized. This interest is included as a part of the cost of the related asset and is depreciated over its estimated useful life.

The budget reflects the revised projections for 2020 as approved by the City Council per the 2021 Annual Operating Budget and Board approved transfers.

May not add due to rounding Page 10




September 30, 2020

Note 5 Long-Term Obligations Outstanding

Statements of Net Position, Page 4, Lines No. 3 and 12

Actual

Over (Under)

Budget

Revenue Bonds Outstanding - JTEC $ 448,975,000 $ 0

Liability for 2012 Lease Repurchase 13,580,000 0

Liability for 2014 Environmental Financing 25,210,000 0

2015 Certificates of Participation Refunding 6,410,000 0

Liability for 2020 SpringNet Network Expansion 35,447,000 4,447,000

529,622,000 4,447,000

Current portion of long-term obligations (34,875,000) 0

Total Long-Term Obligations, Net of Current Maturities $ 494,747,000 $ 4,447,000

Note 6 Production Fuel And Purchased Power


Production fuel and purchased power reported in the Statements of Revenues, Expenses and Changes in Net Position is comprised of the following components:

Actual

Generated/

Purchased

Over (Under)

Budget

MWH

Generated/

Purchased

Over (Under)

Budget

Fuel for Generated Power $ 38,358,000 $ (20,133,000) 1,791,000 (709,000)

Purchased Power

SPP Integrated Marketplace 23,323,000 6,115,000 908,000 236,000

Southwest Power Administration Received 4,892,000 499,000 191,000 61,000

Smoky Hills Wind Project II 5,445,000 (2,618,000) 122,000 (59,000)

Strata Solar 589,000 (144,000) 7,000 (2,000)

Frontier Wind Energy 11,910,000 869,000 651,000 34,000

Diamond Vista Wind Energy 5,231,000 253,000 389,000 19,000

Other Power Supply Expense 2,749,000 2,029,000 0 0

Co-Generation 358,000 358,000 10,000 10,000

Total Production Fuel and Purchased Power $ 92,855,000 $ (12,772,000) 4,069,000 (410,000)

The following is a summary of long-term obligations outstanding, net of current maturities:





September 30, 2020

Note 7 Equity Interest In Partnership Industrial Centers

Statements of Net Position, Page 3 Line No. 13

Statement of Cash Flow, Page 7, Line No. 48

Note 8 Adjustment of Investment Portfolio to Market

Key Indicators, Page 1, Line No, 9

Statements of Net Position, Page 3, Line No. 21


In accordance with the requirements of GASB #31, the investment portfolio value is adjusted to market on a monthly basis. At September 30, 2019, the value of the investments was adjusted to

Current Year

End of Start of Effect on Income /

Summary of Investment Portfolio Value Current Month Current Year Fund Balance

Historical Costs $ 268,991,000 $ 257,529,000

Market Value Adjustment 10,685,000 5,528,000 $ 5,157,000

Carrying Value 279,676,000 263,057,000

For the Partnership Industrial Center - West, as of April, 2003 Greene County became a participant in this partnership. From inception through September 30, 2020, City Utilities had incurred $2,218,000 for improvements,

recognized losses of $148,000, and received distrubutions of $184,000 for a net equity balance of $1,886,000.

City Utilities has a partnership agreement with the City of Springfield, Missouri, the Springfield Area Chamber of Commerce, and the Springfield Business Development Corporation, a Missouri not-for-profit corporation, to govern

the process of development, management, and selling of an industrial center in Springfield, Missouri. Under this agreement, City Utilities is responsible for utility services consisting of natural gas, water, electricity and fiber optic

telecommunication. In addition, City Utilities will pay for site plan consulting services. At the request of the City Council of Springfield, Missouri, City Utilities acquired the land for the first industrial center. The agreement has

delegated to the nine member partnership administrative council, the responsibility for control of the sale of individual parcels in the center. During fiscal year ended September 2006, buy-out of the first Partnership Industrial

Center was completed and final partnership distributions were received in September.

Amounts expended for the industrial centers are accounted for using the equity method. Amounts are reclassified to the equity interest accounts on a one month lag basis, except at September, when the amounts are recorded

on a current month basis. The net profits or losses of the partnership are allocated based on each partner's percentage of the partnership's capital accounts.

reflect increases of $5,528,000. At September 30, 2020, the value of the investments was adjusted to reflect increases of $10,685,000 with the offsetting increase (decrease) to current year net income of

$5,157,000.





September 30, 2020

Note 9 Gain/Loss on Investments - Equity in The Energy Authority



Equity Account Summary:

Cumulative

September 2017

Current Fiscal

Year Activity

Current Month

Balance

Initial Member Investment - Electric $ 752,000 $ 0 $ 752,000Initial Member Investment - Natural Gas 35,000 0 35,000Margin from Energy Transactions Held in Member Account 93,464,000 1,512,000 94,976,000Distributions of Margin from Energy Transactions (Monthly) (76,203,000) (1,512,000) (77,715,000)Equity Contribution 8,256,000 1,481,000 9,737,000TEA Electric Operating Revenue Less Operating Expenses (17,096,000) (674,000) (17,770,000)TEA Natural Gas Operating Revenue Less Operating Expenses (1,105,000) (175,000) (1,280,000)Additional Distributions (5,761,000) 0 (5,761,000)

Equity Balance $ 2,342,000 $ 632,000 $ 2,973,000

See Page 24 for a Year-to-Date Summary of TEA Transactions.

Note 10 (Gain) Loss On Other Activities


In August 2000, City Utilities became an equity member of The Energy Authority (TEA) a power marketing joint venture based in Jacksonville, Florida and incorporated in Georgia. TEA serves as a power marketing corporation

for its members who include MEAG Power (Municipal Energy Authority of Georgia), JEA (Jacksonville Energy Authority), South Carolina Public Service Authority, Nebraska Public Power District, Gainesville Regional Utilities,

American Municipal Power Inc and City Utilities. As a member of TEA, City Utilities benefits from the risk management strategies maintained by TEA which seek to avoid financial losses by limiting exposure as a result of

unexpected unit outages and volatile market prices. City Utilities also receives resource management services from TEA. In April 2002, City Utilities committed up to an additional $9.6 million secured by a combination of $0.4

million cash collateral and $9.2 million member guarantees. In June 2004, the $0.4 million cash collateral was returned; however, the $9.2 million member guarantee was increased to $9.6 million. Effective January 2019, Public

Utility District No. 1 of Cowlitz County, Washington withdrew membership from TEA increasing City Utilities equity interest to 1/17.

This report line includes (gains) losses on sale of surge protection devices, proceeds from the routine sale of SO2 Clean Air Allowances, the sale of NOx allowances, and the sale of Renewable Energy Credits from the Noble Hill

Landfill Renewable Energy Center and Smoky Hills.

The Statements of Revenues, Expenses and Changes in Net Position line "Gain or (Loss) On Investments" includes Gain or (Loss) for: Partnership Industrial Center recognized by City Utilities, Sales of Investment Securities

prior to maturity, and TEA Electric Operating Revenues Less Operating Expenses. The year-to-date ($674,000) reported consists of ($674,000) TEA Electric Operating Revenues Less Operating Expenses and ($2) loss on

investment.

The following schedule identifies activity within the "Equity Interest in The Energy Authority" account for August 2000 through the current month. Note that distributions occur on a monthly basis, less a retainage. The

retainages are used to fund the TEA Operating Revenue less Operating Expenses. From time-to-time, additional distributions are made as listed below - when TEA identifies the retainages are more than adequate to meet

projected expenses.





September 30, 2020

Note 11 Miscellaneous Income (Expense)


Actual

Over (Under)

Budget

Transit Grants $ 4,264,000 $ 1,491,000

Contributions in Aid of Construction 848,000 (1,158,000)

Gain (Loss) on Fixed Assets 458,000 458,000

Misc Income - Other 457,000 116,000

Community Programs (259,000) (16,000)

$ 5,769,000 $ 891,000

Actual

Over (Under)

Budget

Transportation operating income (loss) (Page 6, Line 17) $ (11,158,000) $ 634,000

FTA Preventive Maintenance and Paratransit grant 760,000 (15,000)

FTA Cares Act Grant 2,000,000 2,000,000

FTA and State Operating grant 1,317,000 (496,000)

Medicaid grant 46,000 4,000

Planning grant income 168,000 (3,000)

Planning expenses (26,000) 2,000

Contributions in Aid of Construction 848,000 (1,158,000)

Gain (Loss) on Fixed Assets 0 0

Net income (loss) $ (6,045,000) $ 968,000

The following is a summary of Miscellaneous Income and (Expense)

Operating, preventive maintenance and planning subsidies and related expenses are included in the other income (expenses) category of the Statements of Revenues, Expenses and Changes in Net Position as defined by the

Federal Energy Regulatory Commission (FERC) chart of accounts. Beginning in Fiscal Year 2010 Transit Contributions in Aid of Construction (CIAC) are reported as other income. All other CIAC will be reported with the

audited financial statements only. The schedule below shows the effect of these other operating items on total operating income (loss) for Transit as reported on the Statements of Revenues, Expenses and Changes in Net

Position.





September 30, 2020

Note 12 Price Risk Management Assets




Fiscal Year Status

Volume

(MMBTU)

Initial Strike

Price L/S Contracts Net Initial Value Market Value

Sales/

Expired

Dec/(Inc) to

Natural Gas

Expense

2020 Initial 3,600,000 $2.25 L 360 $ 531,561.60 0.00 0.00 0.00

2020 Expired (3,600,000) $2.25 L (360) $ (531,561.60) 0.00 0.00 499,592.70

$ 0.00 $ 0.00 $ 0.00 $ 499,592.70

2021 Initial 3,600,000 $2.25 L 360 $ 560,811.60 307,170.00 0.00 0.00

2021 Expired (300,000) $2.25 L (30) $ (43,921.80) 0.00 (10,656.90) 0.00

$ 516,889.80 $ 307,170.00 $ (10,656.90) $ 0.00

2022 Initial 900,000 $2.25 L 90 $ 143,015.40 119,670.00 0.00 0.00

2022 Initial 0 $0.00 S 0 $ 0.00 0.00 0.00 0.00

$ 143,015.40 $ 119,670.00 $ 0.00 $ 0.00

Options Total 4,500,000 L 450 $ 703,827.00 426,840.00 0.00 499,592.70

(300,000) S (30) $ (43,921.80) 0.00 (10,656.90) 0.00

$ 659,905.20 $ 426,840.00 $ (10,656.90) $ 499,592.70

Fiscal Year Status

Volume

(MMBTU) Trade Price Contracts Net Initial Value Market Value

Sales/

Expired

Dec/(Inc) to

Natural Gas

Expense

2020 Initial 300,000 $0.00 30 $ 387.30 $ 0.00 $ 0.00 $ 0.00

2020 Expired (300,000) $2.84 (30) $ (387.30) $ 0.00 $ (239,066.40) $ (3,054,196.80)

$ 0.00 $ 0.00 $ (239,066.40) $ (3,054,196.80)

2021 Initial 3,300,000 $3.03 330 $ 4,260.30 (406,500.00) 0.00 0.00

2022 Initial 900,000 $3.06 90 $ 1,161.90 (129,900.00) 0.00 0.00

Futures Total 4,200,000 420 $ 5,422.20 $ (536,400.00) $ (239,066.40) $ (3,054,196.80)

Natural Gas Hedging (Long) $ 709,249.20 (109,560.00) (239,066.40) (2,554,604.10)

Natural Gas Hedging (Short) $ (43,921.80) 0.00 (10,656.90) 0.00

Total Natural Gas Hedging $ 665,327.40 $ (109,560.00) $ (249,723.30) $ (2,554,604.10)

Beginning in 2014, City Utilities acquired Transmission Congestion Rights (TCR’s) in the SPP Integrated Marketplace to manage price risk related to electricity transmission congestion costs. TCR’s are financial instruments that

entitle the holder to receive compensation or requires the holder to remit payment for congestion-related transmission charges. TCR’s meet the definition of a derivative, however, they were used as factors in the cost of

transmission. Therefore, CU’s TCR’s met the normal purchase and normal sales scope exception. As such, GASB Statement 53 - Accounting and Financial Reporting for Derivative Instruments, does not apply. We will monitor

transactions on an annual basis to verifiy that the normal purchase and normal sale exception still applies.

As of September 30, 2020 City Utilities had purchased financial instruments to reduce, or hedge, the volatility of natural gas costs for Fiscal Years 2020 through 2022. Through September the market value of the unexpired

instruments were included as an asset and a liability on the Statements of Net Position with the offset of the monthly fair market value adjustment included as a deferral in "Fuel Adjustments and Natural Gas Refunds" until the

hedging instruments are matched with the corresponding monthly purchased natural gas costs. At September 2020, the value of these financial instruments was adjusted to a current market value of $(110,000).

Natural Gas Options: 2020-2022 Heating Season

Natural Gas Futures: 2020-2022 Heating Season





September 30, 2020

Note 13 GASB Statement No. 65



Note 14 Net Pension Liability


Note 15 Equity Interest in Prepaid Gas Services


Note 16 Regulatory Assets - Asset Retirement Obligations



FASB #143 requires the review and adjustment of the present value of the estimated future costs of these retirement obligations on an annual basis.

City Utilities implemented GASB Statement 68, Accounting and Financial Reporting for Pensions, effective September 30, 2015. This statement requires governments providing defined benefit pensions to recognize their long-

term obligation for pension benefits as a liability. City Utilities participates in LAGERS, an agent multiple-employer public employee retirement system that acts as a common investment and administrative agent for local

government entities in Missouri. LAGERS is a defined benefit pension plan that provides retirement, disability, and death benefits to plan members and beneficiaries. As of September 30, 2019 a Net Pension Liability of

$17,957,000 based on actuarial valuations at February 28, 2019, has been recorded.

At September 30, 2020, City Utilities recorded estimated amounts associated with the closure of the James River Power Station landfill (JRPS) of $1,205,000 in 2045 and the John Twitty Energy Center (JTEC) landfill of

$1,290,000 in 2045. Present value of these obligations at September 30, 2020 was a liability of $781,000 for JRPS and $836,000 for JTEC. For reporting purposes the original cost of retirement of the landfill in the year it was

originally placed in service, net of the accumulated depreciation through September 2020, is included in the Regulatory Assets - Asset Retirement Obligations.

GASB Statement No. 65, Items Previously Reported as Assets and Liabilities went into effect fiscal year 2014. The objective of this Statement is to properly classify certain items that were previously reported as assets and

liabilities as deferred or current outflows or deferred or current inflows of resources. Additionally, GASB 65 requires that debt issuance costs be recognized as expense in the period incurred, except for regulated operations

pursuant to GASB Statement No. 62. In fiscal year 2014, City Utilities reclassified expenditures associated with debt issuance costs as a regulatory asset to be amortized over the remaining life of the related debt.

In accordance with the requirements of Financial Accounting Standards Board Statement (FASB) #143, City Utilities recorded asset retirement obligations at September 30, 2003. Asset retirement obligations are the costs

related to obligations associated with the retirement of tangible, long-lived assets. The present value of future retirement amounts are reported as a liability with an offsetting asset recorded to plant in service and depreciated

over the remaining life through the anticipated retirement date. Costs of future retirement expenditures that are not recoverable through current rates are held as a regulatory asset in deferred charges, then amortized to

expense when recoverable through future rates.

City Utilities entered into a partnership agreement with The Energy Authority (TEA) and American Municipal Power, Inc. (AMP) to participate in prepaid gas services. Amounts expended are accounted for using the equity

method. Amounts are classified on a one month lag basis, except at September, when the amounts are recorded on a current month basis. The net profits or losses of the partnership are allocated on a pro-rata basis divided

equally between the PGS Members participating in the PGS Project. As of September 30, 2020, City Utilities had incurred $90,000 in expenses associated with the start-up of the partnership.


ADDITIONAL INFORMATION

City Utilities of Springfield, MissouriBoard of Public Utilities Additional Information

Summary Of Revenues And Other BillingsYear-To-Date Through September 30, 2020

Electric Natural Gas City UtilitiesOver / (Under) Over / (Under) Over / (Under) Over / (Under) Over / (Under) Over / (Under)

Actual Budget Actual Budget Actual Budget Actual Budget Actual Budget Actual BudgetOperating Revenues: Sales 274,124,035$ (17,036,576)$ 79,635,994$ (12,155,433)$ 791,164$ (265,433)$ 2,649,779$ (2,557)$ 55,105,756$ 1,563,089$ 412,306,729$ (27,896,909)$

Other Operating Revenues: Other Electric Revenue 5,772,308 372,308 0 0 0 0 0 0 0 0 5,772,308 372,308 Rent 260,246 8,246 0 0 0 0 0 0 52,177 46,777 312,424 55,024 Sales Tax Discount 164,358 9,058 42,334 (6,866) 0 0 0 0 33,986 1,986 240,678 4,178 Sewer Billing Fees 574,624 (43,011) 442,765 (2,210) 0 0 0 0 438,645 (1,032) 1,456,034 (46,253) Miscellaneous Service Fees 2,427,669 2,029,269 224,459 4,059 0 0 13,562,000 (1,679,954) 244,625 12,325 16,458,753 365,699 Connect Charges 54,600 31,680 0 0 0 0 0 0 0 0 54,600 31,680 Late Payment Charges 3,837,932 759,632 1,142,668 157,768 0 0 26,065 26,065 794,067 164,067 5,800,732 1,107,532

Total Other Operating Revenue 13,091,737 3,167,182 1,852,226 152,751 0 0 13,588,065 (1,653,889) 1,563,500 224,123 30,095,529 1,890,168

Total Operating Revenue 287,215,772$ (13,869,394)$ 81,488,220$ (12,002,682)$ 791,164$ (265,433)$ 16,237,844$ (1,656,446)$ 56,669,256$ 1,787,212$ 442,402,258 (26,006,741)

Other Income: (A ) Interest ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... 5,416,138 (823,862) Market Value Adjustment ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... 5,157,497 5,157,497 Gain (Loss) on Investments ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... (217,853) 1,282,147 FTA - Preventive Maintenance ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... 760,000 (15,200) FTA - Operating Grants ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... 1,362,530 (492,543) FTA - CARES Grant ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... 2,000,000 2,000,000 FTA - Capital Grants ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... 168,001 (3,360) Transit Charter Revenue ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... 0 0 Contributions in Aid of Construction ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... 848,205 (1,157,839) Misc. (incl. Child Care Lease) ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... 457,416 116,258 Total Other Income ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... 15,951,934 6,063,098

Miscellaneous Billings: (A ) Capital Related ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... 7,767,197 2,000,562 Non-Capital Related ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... 2,679,724 (2,414,539) Purchased Gas Refunds ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... 6,177 6,177 Other ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... 1,985,754 (399,854) Total Miscellaneous Billings ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... 12,438,852 (807,654)

Collections & Deposits: (A ) Sewer Revenue Collections (B ) ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... 40,706,536 (3,482,864) Sales Tax Collections ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... 11,793,208 (32,314) Financing Agreement Receipts ......................... ................................................................................................................................ ......................... ......................... ......................... ......................... 35,446,589 4,446,589 Customer Deposits, Net of Applied ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... 136,421 36,421 Total Collections & Deposits ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... 88,082,754 967,832

Total Revenues and Receipts ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... ......................... 558,875,798$ (19,783,465)$

(A) For City Utilities, these items are not specific to a department, thus are included in the City Utilities total column only.(B) Sewer revenues are shown net of amount owed by CU for sewer use.NOTE: The budget has been adjusted to reflect the October 1 actual balances, Board approved carry-ins, transfers, and Reprojected Budget.Based on the above, revenue is adequate to fund all projects. In the event revenue was not projected to be adequate, a list of deferred projects would be attached to show action taken

Transportation SpringNet/Trunked Radio Water

*See Accompanying Notes to Financial StatementsMay not add due to rounding Page 17


Board of Public Utilities Additional Information

Summary of Disbursements

September 30, 2020

($ In Thousands)

Line

Notes No.

1 Public Utility Operating Fund:

2 Claims And Accounts $ 82,872

3 Wages And Salaries (Net) 4,446

4 Other Payments 239

5 Debt Service Payment 0

6 Investments/Securities Purchased (46,524)

7 Intrafund Transfers (Net) 41,009

8 Disbursements For Current Month 82,041

9 Prior Months Disbursements 453,447

10 Fiscal Year-to-date Disbursements 535,489

11 Non-disbursed Budget Balance 70,582

* 12 Total Budgeted Disbursements (Note 3) 606,071

13 Other Funds:

14 Interfund Transfers 0

15 Intrafund Transfers (41,009)

16 Disbursements For Current Month (41,009)

17 Prior Months Disbursements 26,877

18 Fiscal Year-to-date Disbursements (14,131)

19 Non-Disbursed Budget Balance 40,966

* 20 Total Budgeted Disbursements (Note 3) 26,835

21 All Funds Disbursements:

22 Fiscal Year-to-date Disbursements 521,358

23 Non-disbursed Budget Balance 111,548

* 24 Total Budgeted Disbursements (Note 3) $ 632,906



Category Fuels NonCapital Capital Total Fuels NonCapital Capital Total Fuels NonCapital Capital Total

A. POWER GENERATION 0 22,953,786 4,168,612 27,122,398 0 23,182,244 4,755,562 27,937,806 0 228,458 586,950 815,408

B. FUELS 123,628,853 797,171 0 124,426,024 142,567,986 793,385 0 143,361,371 18,939,133 (3,786) 0 18,935,347

C. ELECTRIC TRANSM AND DISTRIB 0 31,977,481 18,977,727 50,955,208 0 30,307,634 22,115,610 52,423,244 0 (1,669,847) 3,137,883 1,468,036

D. NATURAL GAS TRANSM AND DISTRIB 0 6,120,215 11,458,314 17,578,529 0 6,064,521 11,972,148 18,036,669 0 (55,694) 513,834 458,140

E. WATER SUPPLY AND TREATMENT 0 4,776,718 506,584 5,283,302 0 5,730,258 1,705,980 7,436,238 0 953,540 1,199,396 2,152,936

F. WATER DISTRIBUTION 0 5,375,394 11,754,175 17,129,569 0 5,648,317 13,051,772 18,700,089 0 272,923 1,297,597 1,570,520

G. TRANSIT 0 4,421,707 961,740 5,383,447 0 4,991,218 1,619,347 6,610,565 0 569,511 657,607 1,227,118

H. FACILITIES 0 6,316,894 5,916,098 12,232,992 0 6,171,834 7,787,979 13,959,813 0 (145,060) 1,871,881 1,726,821

I. VEHICLES AND EQUIPMENT 0 2,413,841 2,114,552 4,528,393 0 2,632,590 3,905,862 6,538,452 0 218,749 1,791,310 2,010,059

J. SPRINGNET 0 5,027,738 55,061,416 60,089,154 0 6,011,330 55,593,067 61,604,397 0 983,592 531,651 1,515,243

K. INFORMATION TECHNOLOGY 0 9,887,825 1,899,351 11,787,176 0 11,151,900 1,838,944 12,990,844 0 1,264,075 (60,407) 1,203,668

L. HUMAN RESOURCES 0 51,684,186 0 51,684,186 0 55,749,165 0 55,749,165 0 4,064,979 0 4,064,979

M. FINANCE 0 6,028,447 0 6,028,447 0 6,657,147 0 6,657,147 0 628,700 0 628,700

N. GENERAL OPERATIONS SUPPORT 0 3,983,528 0 3,983,528 0 4,134,288 19,500 4,153,788 0 150,760 19,500 170,260

O. ADMINISTRATIVE SUPPORT 0 5,550,965 0 5,550,965 0 6,372,297 10,000 6,382,297 0 821,332 10,000 831,332

P. CUSTOMER SUPPORT 0 10,639,086 69,741 10,708,827 0 12,024,143 120,000 12,144,143 0 1,385,057 50,259 1,435,316

Q. DEBT SERVICE 0 55,529,633 0 55,529,633 0 55,734,630 0 55,734,630 0 204,997 0 204,997

R. NON-UTILITY 0 71,375,641 0 71,375,641 0 77,741,677 4,113,250 81,854,927 0 6,366,036 4,113,250 10,479,286

SUBTOTAL PROJECT EXPENDITURES 123,628,853 304,860,256 112,888,310 541,377,419 142,567,986 321,098,578 128,609,021 592,275,585 18,939,133 16,238,322 15,720,711 50,898,166

GUARANTEES - TEA 0 0 0 0 0 9,642,858 0 9,642,858 0 9,642,858 0 9,642,858

TOTAL PROJECT EXPENDITURES 123,628,853 304,860,256 112,888,310 541,377,419 142,567,986 330,741,436 128,609,021 601,918,443 18,939,133 25,881,180 15,720,711 60,541,024

Total Company Summary of Expenditures by Category

Through September 30, 2020


/ - - - - - - - - - - - - - 2020 YTD ACTUALS - - - - - - - - - - - - - / / - - - - - - - - - - - - 2020 ANNUAL BUDGET - - - - - - - - - - - - / / - - - - - - - - - - - - - BUDGET REMAINING - - - - - - - - - - - - - /



2020 2020

Original Approved General Manager Board General Manager Board Revised

Category Budget Carry-Ins Previously Approved Previously Approved Approved * Pending Approval** Budget

A. Power Generation 26,118,864$ 1,348,942$ 470,000$ 27,937,806$

B. Fuels 167,065,247 (9,063,066) (14,640,810) 143,361,371

C. Electric Transmission and Distribution 47,248,702 1,567,000 3,607,542 52,423,244

D. Natural Gas Transmission and Distribution 13,995,319 50,000 3,991,350 18,036,669

E. Water Supply and Treatment 6,220,896 50,000 1,165,342 7,436,238

F. Water Distribution 17,015,751 627,000 1,057,338 18,700,089

G. Transit 7,163,565 47,000 (600,000) 6,610,565

H. Facilities 13,129,429 920,384 (90,000) 13,959,813

I. Vehicles and Equipment 5,044,672 1,154,280 339,500 6,538,452

J. Springnet 39,601,897 750,000 21,252,500 61,604,397

K. Information Technology 12,609,544 235,000 146,300 12,990,844

L. Human Resources 58,698,268 - (2,949,103) 55,749,165

M. Finance 6,334,531 326,500 (3,884) 6,657,147

N. General Operations Support 4,113,788 40,000 - 4,153,788

O. Administrative Support 6,557,222 135,000 (309,925) 6,382,297

P. Customer Support 12,172,143 15,000 (43,000) 12,144,143

Q. Debt Service 62,201,155 (6,524,167) 57,642 55,734,630

R. Non-Utility 83,469,918 9,608,698 (11,223,689) 81,854,927

Total Company Project Expenditures 588,760,911$ 1,287,571$ -$ 2,227,103$ -$ -$ 592,275,585$

Non Capital 326,026,371$ (3,457,202)$ -$ (1,470,591)$ -$ -$ 321,098,578$

Capital 96,453,010 13,807,839 - 18,348,172 - - 128,609,021

Fuels 166,281,530 (9,063,066) - (14,650,478) - - 142,567,986

Total Company Project Expenditures 588,760,911 1,287,571 - 2,227,103 - - 592,275,585

Guarantees - The Energy Authority - 9,642,858 - - - - 9,642,858 Total Budget Appropriation 588,760,911$ 10,930,429$ -$ 2,227,103$ -$ -$ 601,918,443$

* Transfers within Categories; reclassifications between Categories due to accounting treatment, labor or organizational changes.

** Transfers between Categories greater than $1.

Transfers and Reclassifications



Budget Changes by Category

Year-To-Date Through September 30, 2020


Date Category Project Description Amount

09/2020

-


09/2020 Electric Transmission & Distribution Revenue Producing Proj-Elec 1,400,000 Electric Transmission & Distribution Storms - Line Maintenance 1,200,000 Electric Transmission & Distribution Matls/Supp Inv Incr - Elec T&D 2,000,000 Springnet Fiber Expansion 5,000,000 Non-Utility Contingency Funding Source (9,600,000)

-


09/2020

-

Transfers Between Categories - Pending Board Approval

General Manager Approved Transfers and Reclassifications

Board Approved Transfers Between Categories

City Utilities of Springfield, MissouriBoard of Public Utilities Additional Information

Approved Transfers and ReclassificationsMonth of September

May not add due to roundingPage 21



Accounts Receivable - Aging

September 30, 2020

($ in Thousands)

NOTES

Line

No. 0-30 Days 31-60 Days 61-90 Days Over 90 Days Total % of Total

Over

(Under)

Budget

1 Accounts Receivable

2 Current Accounts $ 22,875 $ 22,875 86% $ (1,340)

3 Delinquent Accounts:

4 Regular Accounts:

5 Residential 13,370 $ 2,447 $ 243 $ 70 $ 2,760 10%

6 Commercial/Industrial 9,505 404 23 13 440 2%

7 Final Accounts 245 136 234 616 2%

8 Total Delinquent Accounts 3,096 402 317 3,816 14% (146)

9 Total Currently Due $ 22,875 $ 3,096 $ 402 $ 317 $ 26,691 100% $ (1,486)

10 Less Allowance for Doubtful Accounts 500 2% 92

11 Accounts Receivable

12 Net of Allowance for Doubtful Accounts $ 26,191 98% $ (1,579)

13 Percent of Related Month Sales 58.99% 7.66% 1.01%

14 Bad Debts Written Off, Net of Recoveries

15 (Fiscal Year-to-Date) $ 1,054 $ (349)

* See Accompanying Notes To Financial Statements

May not add due to rounding

Page 22



Accounts Receivable - Aging

Year-to-Date Through September 30, 2020

0

500

1,000

1,500

2,000

2,500

3,000

3,500

31-60 Days 61-90 Days Over 90 Days

Accounts Receivable Aging($ In Thousands)

Prior Year

Current Year

0

10,000

20,000

30,000

40,000

50,000

60,000

31-60 Days 61-90 Days Over 90 Days

Number of Service AgreementsBy Aging Category

Prior Year

Current Year

Page 23



Summary of TEA Transactions

Fiscal Year To Date Through September 2020

($ in Thousands)

TEA TEA TEA TEA TEA

Sales Purchases Total Costs Total Impact

Operating Revenues: 2,189$ -$ 2,189$ -$ 2,189$

Operating Expense:

Production Fuel & Purchased Power 687 - 687 687

Natural Gas Purchased 175 175

Other Production

Distribution And Transmission (10) (10) (10)

Bus And Garage Operations

Other Services

Customer Accounts

Administrative And General - - -

Franchise Requirements

Duplicate Charges - credit

Maintenance

Depreciation And Amortization

(Gain) Loss On Other Activities

Payment In Lieu Of Taxes 66 66 66

Total Operating Expense 742 - 742 175 917

Operating Income (Loss) 1,446$ -$ 1,446$ (175)$ 1,272

Other Income (Expense)

Gain Or (Loss) On Investments (674) NET TEA IMPACT TO NET INCOME 597$

Electric Natural Gas


Page 25

City Utilities of Springfield, Missouri Board of Public Utilities Additional Information

Professional Services Contracts Greater than $100,000 Entered into During Month Ended September 30, 2020

Contract

Professional Area Firm Selected Description of Work Amount

Facilities Management ESC Inc. MEP Consultant Service $350,000 (1)

Facilities Management Anderson Engineering, Inc. Surveying Services $990,000 (2)

Electric Line Engineering Toth & Associates, Inc. Engineering Services $3,000,000 (3)

1 Change order increasing not-to-exceed from $200,000 to $350,000. 2 Change order increasing not-to-exceed from $790,000 to $990,000. 3 Change order increasing not-to-exceed from $2,000,000 to $3,000,000.

October November December January February March April May June July August September

Off System Sales Margin $586,564 $483,453 $40,805 $4,124 $23,766 $31,928 ($13,196) $23,470 $168,557 $383,346 $314,034 $133,813

Purchase Differential ($34,121) ($5,843) $198,112 $21,107 $115,310 $98,840 $13,369 $519,335 ($14,374) ($26,552) $123,405 $289,492

Net Market Benefit $552,443 $477,609 $238,917 $25,231 $139,077 $130,768 $173 $542,805 $154,183 $356,795 $437,439 $423,305

Off-System Sales Margin is the net gain or loss realized from selling generation that exceeds our native load into the SPP Integrated Marketplace. Purchase differential is the benefit that City Utilities realizes by

purchasing power in the SPP Integrated Marketplace. It is calculated by comparing the cost of purchasing power from the SPP Integrated Marketplace to the estimated cost to generate the same power using

owned assets. The Net Market Benefit is the combined value of Off-System Sales Margin and Purchase Differential. The Net Market Benefit does not include the cost of transmission.

($ in Thousands)



Net Market Benefit

September 30, 2020

$0.00

$0.50

$1.00

$1.50

$2.00

$2.50

$0

$250

$500

$750

October November December January February March April May June July August September

Net Market Benefit

Avg Natural Gas Price


43

Upon a motion duly made by Mr. Joe Reynolds, and seconded by Mr. Don Woody, the Board unanimously approved Item 5a.

6. The next item to come before the Board was the General Manager’s report. Ms. Stephanie O’Connor, Associate General Manager – IT & Administration, gave

a CU Safety Week Update presentation as follows:

CU Safety Week Update

October 29, 2020

Safety Days Pre-2020

Safety Vendors

Single Day Event

Keynote Speaker and Breakout Sessions

Safety Awards

25

26

Safety Week 2020

Supervisors are to conduct the scheduled daily Tailgate Talk with their employees

Supervisor’s booklet has a written script to read to employees before going over the Tailgate Talk

Employee’s booklet will have all the Tailgate Talks for the week included

After the Supervisor completes the Tailgate Talk, they are to pass around an attendance sheet

Supervisor ensures the attendance sheets are forwarded to the Safety Department

Supervisor BookletEmployee Booklet

October 26-30

Safety TopicsTopics for all groups

• Skin Cancer

• Eye Protection

• Distracted Driving

Topics specific to different groups

• Excavations

• Struck-by, Caught-in

• Work Zone

• Slips, Trips and Falls

• Personal Security

• Chemical Safety

• Hypothermia

27

28

Safety Week Giveaway• Employees who attends 4 out of the 5 Tailgate

Talks are eligible

Incentives

Big Poppy rechargeable flashlight and soft glow lantern

29

30

47

Chair Rector asked if any Board members had any business that may properly come before the Board; there were none. Chair Rector then asked if any Board members had any announcements for the Board to hear; there were none.

Chair Rector stated that the Retreat portion of the meeting would begin. 7. Mr. Dwayne Fulk, Associate General Manager – General Counsel, Mr. Kelly

Laurie – Director – IT, and Mr. Jeff Parkison gave a Strategic Plan presentation as follows:

Strategic Plan

October 29, 2020

VisionDeliver world-class services and exceptional value to our customers.

Mission Enhance the quality of life in our community through innovation,

engagement, and stewardship.

33

34

TRANSFORMATIONAL STRATEGIES—How we plan to evolve

FOUNDATIONAL STRATEGIES—Who we are & what we do

Grow DiversifyInnovate

COREVALUES

CORE VALUES—Guiding Principles

RESPONSIBLE DEPENDABLE EXCELLENCE

VisionDeliver world-class services and exceptional value to our customers.

Mission Enhance the quality of life in our community through

innovation, engagement, and stewardship.

35

36

50

Next, Mr. Gary Gibson, General Manager, gave an update on Jeff Wilson, Electrician in Substation Operations, who was injured on the job while the Board meeting and retreat was in session.

8. Mr. Amy Derdall and Ms. Renee Vines, Associate General Manager – Chief

Internal Auditor, gave an Audit Best Practices presentation as follows:

Audit Best Practices

October 29, 2020

Purpose of External Audit

• Examination of financial statements• Independent review of internal controls• Assurance on compliance with regulations

2

3

Importance of External Audit

• Required by City Charter• Lends credibility to financial

statements• Establishes assurance and

trust with stakeholders

Audited Financial

Statements

Lenders

Managers

Governing Bodies

Suppliers

Customers

Rating Agencies

External Auditor Selection ProcessFollow competitive bidding procedures

• Send RFP to top 15 accounting and audit firms• Review committee

Establishes review criteria Evaluates proposals Members from: Financial Reporting, Internal Audit, and City of

Springfield • Recommendation to Board of Public Utilities committee for

approval

4

5

External Audit Firm History

* National rankings are based on number of employees and total revenue at the time of audit service.

Auditor Years of Service

National Ranking*

Contract Period

One‐year renewals

RFP Solicitation

Arthur Anderson 1994 ‐ 1995 1 Two‐year None Top‐5

Coopers & Lybrand 1996 ‐ 1997 3 Two‐year None Top‐5

Price Waterhouse Coopers 1998 ‐ 1999 4 Two‐year None Top‐5

KPMG 2000 ‐ 2009 6 One‐year 4 Top 20

BKD 2010 ‐ 2020 12 One‐year 4 Top 15

Change in Audit Firm Benefits

*2018 KPMG LLP Audit Committee Institute Survey

6

7

Change in Audit Firm Risks

*2018 KPMG LLP Audit Committee Institute Survey

Changing External Auditors

Advantages

• Fresh perspective• Price competition

Disadvantages

• Additional time• Additional training• Lack of institutional

knowledge

8

9

Resources• Public Company Accounting Oversight Board

No requirement for mandatory audit firm rotation• Government Financial Officer’s Association

Multi-year agreements RFP process Natural rotation process

• American Institute of CPA’s – Governmental Audit Quality Center Multi-year agreements RFP Process No requirement for rotation

Summary

• No requirement for external audit firm rotation• Evaluate external auditors annually for:

Quality of service and sufficiency of resources Relevant industry experience Communication with stakeholders Independence, objectivity and professional

skepticism• Follow CU procurement procedures

10

11

56

9. Mr. Steve Stodden, Associate General Manager - Operations, introduced Mr. Matt Crawford, Director – Transit. Mr. Crawford gave a Transit Overview presentation as follows:

Transit Overview

October 29, 2020

Transit Begins in 1881

13

14

The Early Years of Transit

Glory Days of Transit 1930s-1950s

15

16

Obligation & Commitment • City of Springfield Charter

– Article XVI, Section 16.1 – Definitions• City Utilities’ Mission

– To responsibly serve our customers and community beyond their expectations.

– “If we are going to be in the transit business, we are going to do it the best that we can.” – Scott Miller, General Manager

Public Transportation

TRANSIT SYSTEMTotal Revenue Passengers 900,523Bus Miles Operated 975,125Bus Hours Operated 68,901Miles of Route 241Bus Stops 750Bus Passenger Shelters 95Bus Benches 200

Motor Buses OwnedRegular Street-Service Buses 27Demand-Response Buses 6

CU Transit Center

17

18

Transit Staff

Bus Operators 51Administrative Staff 10

Operations Manager 1Bus Supervisors 4Dispatchers 2Office Administrator 1Grants Analyst 1Transportation Planner 1Director 1

Total Staff 61

Fixed Route Service

19

20

Fixed Route Service• 18 buses at peak weekday service• 6 am – 11 pm, daily• 12 weekday routes• 7 evening routes• $12.96 cost per passenger• $0.60 to $1.25 fare per ride

WEEKDAY SERVICE

21

22

NIGHTS, WEEKENDS, & HOLIDAYS

Complementary Paratransit

ACCESS EXPRESS

23

24

Complementary Paratransit• Access Express• Eligibility Process• 6 paratransit buses available• 6 am – 11 pm, daily• City Limits• 13,350 passengers• $55.63 cost per passenger• $1.50 to $2.50 fare per ride

System Service Metrics

• On-Time Performance = 82%• Farebox Recovery Ratio = 7.45%• Operating Expense per Passenger = $12.96• Operational Cost per Service Hour = $100/hr

25

26

Who Rides Transit?• 22% are under 25 years old• 6% are 65 or older• >60% earn less than $15,000/year• 37% are traveling to/from work• 72% don’t drive or do not have a car available• 68% ride every day

Who Pays For Transit?

CU Customers$6,045,713

54%

State Government$43,401

0%

Federal Government$2,201,556

20%

CARES Act$2,000,000

18%

Advertising$83,392

1%

Passengers$753,347

7%

2020 Transit Funding

*Approximately 3% of City Utilities Total Expenses

27

28

2020 AASHTO ReportAmerican Association of State Highway and Transportation Officials

Challenges• Ease of Car Ownership

– Minimal Congestion– Plentiful Parking

• Lack of Density & Proximity of Services• Declining Ridership

– Low Fuel Prices– Strong Local Economy

• Competition (BearLine, Shuttles, TNCs, etc.)

29

30

CARES Act• $7.6m awarded May 4, 2020, no expiration date• Primary Goals

• Recover lost revenue from farebox• Service continuity• COVID-19 Response and Protection

• CU Transit applied for 25% spend down, used toward labor• CU plan to spend CARES over four years• Future payments to labor (applies at 100%); frees up other federal grant

money

COVID-19 Response• Workforce Preservation Plan March 22- May 30, 2020 (2 teams)• Protection

• Temporary Barriers (allowed front door entry, farebox collection)

• Gloves, Masks, Anti-Fog for drivers• Masks & Hand Sanitizer hand outs at the Transit Center• Masks, hand sanitizer, signage, second standee line• Limited Bus Capacity (average passengers per trip)• Permanent Barriers – install to begin by end of year

31

32

Future Plans• Electric Buses

– Low/No Emissions Grant in progress (Arrive May 2021)• Training Simulator

– Revamp Operator Training• Sidewalks

– Partnership with City on Division Street; MODOT on Glentsone– ADA Plan

• Camera System Live Streaming (mSet)

Crisis Cold Weather Shelter Trips• Shelter Season November 1, 2019 – March 31, 2020

– One bus, one operator, two trips, 50 passengers each trip– The Connecting Grounds, East Sunshine Church of Christ,

Veterans Coming Home, Grace United Methodist• 7,310 Trips Last SeasonThis Year…

• ESCC limit is 50; Bus has limited capacity• Same arrangement with sheltering community

33

34

Election Day• Free Rides November 3• General polling location

Benchmarking• Columbia, MO

– 40 Minute Service; Service Ends at 8:00 PM; No Sunday Service; $1.50 Fare

• Little Rock, AR– 30 Minute Service; Service Ends at 9 PM (weekday), 7 PM (Sat.), 5 PM (Sun.); $1.35

• Wichita, KS– 30/60 Minute Service; Service Ends at 7:30 PM; No Sunday Service; $1.75 Fare

• Tulsa, OK– Only 4 routes w/30 Min. Service; No Sunday Service; $1.50 Fare

• Des Moines, IA– 30/60 Minute Service; Service Ends 11:45 PM (week), 9:45 PM (Sat.), 6:40 PM (Sun.); $1.75 Fare

35

36

69

Mr. Joe Reynolds left the meeting at 2:33 p.m. and returned at 2:45 p.m.

Next, Chair Rector proposed that if the majority of Board members favored it, he requested a motion to hold a closed session meeting for the purpose of discussing matters pursuant to Sections 610.021 (1 and 12) RSMo., and that this meeting, record and vote be closed and the Board shall stand adjourned at the end of the closed session. Mr. Joe Reynolds made the motion and Ms. Louise Knauer seconded the motion. Chair Rector requested a roll call vote. Those in favor of conducting this closed session:

Yes: Scott Bratcher Kristin Carter Louise Knauer Rob Rector Joe Reynolds Lynn Rowe Denise Silvey Nancy Williams Jennifer Wilson Don Woody No: None

The meeting adjourned at 3:00 p.m. Approved By: __ Jennifer Wilson, Secretary Board of Public Utilities of Springfield, Mo.

10-29-2020

*This meeting may be accessed by the public in person or by the following methods: 1. Springfield television: over the air and Mediacom channels 15-1 and 80 or AT&T U-Verse channel 99 (items 1 – 6 only) 2. City Utilities of Springfield, MO Facebook page or https://cityview.springfieldmo.gov/livestream (items 1 – 6 only)

If you need special accommodations when accessing this Board of Public Utilities Meeting, please notify the Executive Assistant at 417-831-8610 as soon as possible prior to the scheduled meeting. **Persons wishing to make oral comments to the Board must notify the Executive Assistant before the meeting and provide in writing their name, address, the name of person or group, if any, they are representing, and the agenda item, if any, upon which they wish to speak.

NOTICE AND TENTATIVE AGENDA OF A REGULAR MEETING AND RETREAT OF THE BOARD OF PUBLIC UTILITIES

OF THE CITY OF SPRINGFIELD, MISSOURI

To be held Thursday, October 29, 2020, at Noon* City Utilities’ Training Center Classroom at 301 E. Central Street

MEETING 1. Opening Remarks Denise Silvey

• MPUA Paul Jensen Individual Achievement Award Gary Gibson 2. Approval of Minutes (2a) (action item) Denise Silvey 3. Public Comment** Denise Silvey 4. Committee Reports Committee Chairs

(any anticipated actions would be listed with the appropriate Committee)

5. Financial Statements (5a) (action item) Amy Derdall 6. General Manager’s Report Gary Gibson

• IT & Administration Update Stephanie O’Connor RETREAT 7. City Utilities’ Strategic Plan Dwayne Fulk 8. Audit Best Practices Amy Derdall/Renee Vines

9. Transit Overview Steve Stodden Any other items that may properly come before the Board. Closed Item(s) Following completion of its agenda, the Board will, if a majority approves, hold a closed session to consider matters included within the purview of Section 610.021 (1, 2, 3, 9, 10, 11, 12, 13, 14, 15, 16, 17, 18, 19, 20, 21 and/or 22) RSMo. (Resolution for any closed session will specify subjects.) Posted: Wednesday, October 28, 2020 Estimated Meeting Time: Noon – 5 p.m.

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