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AGENDA
BENTON COUNTY PUBLIC UTILITY DISTRICT NO. 1 COMMISSION MEETING
Tuesday July 14, 2020 9:00 a.m. 2721 West 10th Ave., Kennewick
The meeting is open to public attendance via telephonic means. The conference call line is: 1-469-998-5874 ID: 170 702 675#
1. Pledge of Allegiance 2. Public Comment 3. 2020 Bond Issue Discussion Info. Only/Jon Meyer/Dick Shober, Piper Sandler & Co./Christine Pihl, RBC Capital Markets 4. Treasurer’s Report 5. APPROVAL OF CONSENT AGENDA (All matters listed within the Consent Agenda have been distributed to each member of the Commission for reading and study, are considered to be routine, and will be enacted by one motion of the Commission with no separate discussion. If separate discussion is desired by any member of the Commission, that item will be removed from the Consent Agenda and placed on the Regular Agenda by request.) a) Minutes of regular commission meeting of June 23, 2020. b) Vouchers dated July 14, 2020. c) Resolution No. 2548, Retired Equipment Surplus. 6. Report from Management 7. BUSINESS AGENDA a) Motion Extending Temporary Changes to the District’s Customer Service Rates and Policies Action Item/Jon Meyer b) Broadband Business Update Info. Only/Chris Folta/Rich Nall, NoaNet c) Benton PUD 2020 Integrated Resource Plan Update Info. Only/Kevin White d) Motion Approving Wind Power and Clean Energy Policy Perspectives Report Action Item/Rick Dunn 7. Other Business 8. Future Planning 9. Meeting Reports 10. Executive Session (To request an accommodation to attend a commission meeting due to a disability, contact [email protected] or call (509) 582-1270, and the District will make every effort to reasonably accommodate identified needs.)
1
Business Agenda
Second Reading
Consent Agenda
Info Only/Possible Action
✓ Info Only
COMMISSION MEETING AGENDA ITEM
Subject: 2020 Bond Issue Discussion
Agenda Item No:
Meeting Date: July 14, 2020
Presented by: Jon Meyer Staff Presenting Item
Approved by (dept): Jon Meyer Director/Manager
Approved for Commission review:
Rick Dunn General Manager/Asst GM
Motion for Commission Consideration
None. Background
Staff will be joined by the District’s Financial Advisor, Dick Shober of Piper Sandler & Co., and the District’s Underwriter, Christine Pihl of RBC Capital Markets to discuss details related to a 2020 Bond Issue. This includes the District’s debt profile, debt service reserve fund requirements, opportunities to refinance, and details related to issuing bonds. Summary
Details related to a 2020 Bond Issue will be discussed. Fiscal Impact
Issuing bonds will help spread the costs of core infrastructure over time to better align the costs with the benefits resulting in ratepayer equity. Issuing bonds removes the need for a near-term rate increase during a time of economic downturn while maintaining the Strategic Capital Plan and financial metrics.
3
2
July 14, 2020
Bond Issue Discussion
3
Introductions
▪ Financial Advisor
▪ Dick Schober, Piper Sandler & Co.
▪ Underwriter
▪ Christine Pihl, RBC Capital Markets
4
Agenda
▪ Review of Debt Service Schedules (Jon)
▪ Debt Service Reserve Fund Fundamentals (Jon)
▪ Market Overview (Christine)
▪ Current bonds & bondholders (Christine)
▪ What a $20M bond issue looks like (Christine)▪ Concepts of par amount v. what gets cleared
▪ What happens at closing
▪ Refinancing Opportunities (Christine)▪ Specific Mechanics of Refinancing 2011 and 2016 Bonds
▪ Abilities to Optimally Structure Refinancing
▪ Reduction of Debt Service Reserve Fund Requirement
▪ Mitigate annual debt service amounts in the next couple of years
5
Current Debt Service Schedule
$-
$1.0
$2.0
$3.0
$4.0
$5.0
$6.0
$7.0
$8.0
Millions
2010 2011 2016 Avg Annual
6
Debt Service Schedule with a 25 year $20M Bond Issue Presented June 9, 2020 (Interest only until 2030)
$-
$1.0
$2.0
$3.0
$4.0
$5.0
$6.0
$7.0
$8.0
Mill
ion
s
2010 2011 2016 2020 Avg Annual
As the 2020 Bond Issue develops with our
Underwriter and Financial Advisor the 2020 debt
service amounts could change slightly (will discuss
later)
7
Debt Service Reserve Fund (DSRF) Defined
▪ DSRF is a reserve fund that bondholders have first right to in case of default
▪ DSRF was defined in past Benton PUD bond issues as the following
▪ 125% of average annual debt service (AADS) (Least of available options)
▪ Bond insurance can be used to satisfy this requirement
▪ Total requirement in 2021 is $3.7M (without factoring in 2020 bonds)
▪ Currently funded with $1.1M cash and surety from 2001
▪ The surety from 2001 (refinanced in 2011) expires in 2021
▪ Benton PUD has $2.6M designated to fund the DSRF to replace it in 2021
8
Debt Service Reserve Fund (DSRF) History
▪ Historically, bond issuers included a DSRF in their bond covenants
▪ Issuers with good credit ratings started not including DSRF requirements in the past 5+ years
▪ DSRF related to Benton PUD’s outstanding bonds
▪ 2010 – DSRF included in covenants
▪ 2011 – DSRF included in covenants
▪ 2016 – DSRF NOT included in covenants
▪ 2020 Bond Issue – DSRF will NOT be included in covenants
9
Debt Service Reserve Fund (DSRF) “Consent”
▪ If an outstanding bond issue has DSRF requirement, then DSRF amount must include all new bond issues, unless 2/3 of all bondholders consent to not fund▪ 2016 Bond Covenants were written so that those bondholders “consented”
▪ 2020 Bond Covenants will be written to that these bondholders will “consent”
▪ Even with 2020 Bond Issue, 2/3 requirement to achieve consent would still not be achieved▪ Currently, this means a 2020 bond issue may result in additional $1.2M funding of DSRF
which either:▪ reduces proceeds of bond issue; or
▪ Requires the bond issue to be “sized up” to fund this requirement
▪ Consent = 2/3 of outstanding bonds have covenants that don’t require DSRF▪ Practically speaking, this is accomplished by refinancing a small amount of outstanding
bonds without consent with new bonds that do not have a DSRF requirement
10
Debt Service Reserve Fund (DSRF) Options
▪ Consent can be achieved by refinancing remaining 2011 bond issue▪ Refinance final principal payments in 2020 and 2021 of $9.8M total
▪ NPV cost of ~$80k (today’s market)
▪ Achieves “Consent” for new bond issues
▪ However… still leaves existing bonds (2016) subject to the DSRF requirement
▪ Refinancing some of the 2016 bonds reduces DSRF requirement▪ Choose the most economical maturities to refinance to lower the DSRF requirement
▪ NPV cost of ~$230k (today’s market)
▪ These two items together result in:▪ No additional DSRF for 2020 bonds (eliminates $1.2M of required funding)
▪ Lowers requirement from $3.7M next year to $2.4M (frees up $1.3M)
▪ In total, these two steps eliminate the need to set aside $2.5M in cash
11
Debt Service Reserve Fund (DSRF) Options
▪ Refinancing 2011 and pieces of 2016 also provide opportunity to level annual debt service over the next two years
▪ May result in pushing some principal (~$1M) out in future years from what otherwise would have occurred
▪ Christine will cover in more detail
12
Transition to Christine Pihl’s Presentation
13
STRICTLY PRIVATE AND CONFIDENTIAL
Benton PUD
Financing Overview
July 14, 2020
14
Market Update
15
RBC Capital Markets2
0.70%
1.70%
2.70%
3.70%
4.70%
5.70%
Jan-09 Jan-10 Jan-11 Jan-12 Jan-13 Jan-14 Jan-15 Jan-16 Jan-17 Jan-18 Jan-19 Jan-20
10 Yr 20 Yr 30 Yr
Current Municipal Market Conditions: “AAA” MMDTax-exempt rates are at their lowest levels of the decade
“AAA” MMD January 1, 2009 to Present Shift in “AAA” MMD Since July 2019
Source: TM3, Thomson Reuters10, 20, and 30 year “AAA” MMD shown to represent different average lives of municipal transactionsRates as of July 2, 2020
0.70%
1.00%
1.30%
1.60%
1.90%
2.20%
2.50%
2.80%
3.10%
3.40%
Jul Aug Sep Oct Nov Dec Jan Feb Mar Apr May Jun Jul
July 1, 2019 to Present10 Year 20 Year 30 Year
Maximum 2.79% 3.18% 3.37%Minimum 0.78% 1.19% 1.38%Average 1.32% 1.80% 1.99%
January 1, 2009 to Present
MaximumMinimumCurrentShift in 30-year "AAA" MMD
2013 2014 2015 2016 2017 2018 20191.33% -1.34% -0.01% 0.27% -0.51% 0.47% -0.93%
30 Year5.08%1.38%1.63%
10 Year3.53%0.78%0.90%
20 Year4.89%1.19%1.43%
Series 2010Series 2011 Series 2016
16
RBC Capital Markets3
0.00%
1.00%
2.00%
3.00%
4.00%
5.00%
1 3 5 7 9 11 13 15 17 19 21 23 25 27 29
Current MMD Series 2010 (BABs) Series 2011 Series 2016 Indicative Scale
Historical View: Tax-Exempt Yield TrendsInterest rates are low with a flat yield curve
• Source: Thomson Reuters’ TM3, RBCCM as of July 6, 2020
Interest Rate (%)
0.00
1.00
2.00
3.00
4.00
5.00
6.00
7.00
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 300.00
1.00
2.00
3.00
4.00
5.00
6.00
7.00
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30
Current 2015 Low2-Yr Range 20-Yr Range 2020 Low
“AAA” GO MMD Yield Curve
MMD Yields are at All-Time Lows
Indicative Benton PUD scale
Rate Comparison:2020 Bonds* 2016 Bonds:
Arbitrage yield: 2.05% 2.50%All-in TIC: 2.83% 3.26%Average Life: 18.9 years 16.85 years
Final maturity of 2020 BondsAverage life of 2020 Bonds
* Preliminary; subject to change
17
RBC Capital Markets4
Federal Infrastructure/Stimulus LegislationU.S. House of Representatives Passes INVEST in America Act (H.R.2)
Provisions include: 1) restoration of direct pay bonds (Qualified Infrastructure Bonds or QIBs), 2) restoration of tax-exempt advance refundings, 3) increase of the annual issuance limit for bank qualified bonds from $10 million to $30 million, 4) raise the per state annual private activity bond volume cap, and 5) authorize a new category of School Infrastructure Bonds (SIBs) with 100% interest subsidy.
Two Focused Companion Senate Bills introduced
• Restoration of Direct Pay Bonds (American Infrastructure Bonds)• Reinstatement of tax-exempt advance refunding bonds.
Senate leadership against a broad infrastructure bill; possibility of a more modest phase 4 COVID-19 stimulus package In September
1
Key Areas of Market Focus Going Forward
Markets Focused on Recent COVID-19 Resurgence in Several StatesEquity prices pushed steadily higher last week as positive economic reports and some encouraging news on the coronavirus vaccine front offset concerns over increasing infection rates across 36 states.
3
Road to RecoveryThe June jobs report propelled markets forward, as the unemployment rate fell from 13.3% to 11.1%; below consensus estimates of 12.5%. Hiring in June was heightened by partial business re-openings and continued government aid.
2
18
Bond Portfolio
19
RBC Capital Markets6
Outstanding Debt and Current BondholdersCurrent Ratings:Aa3 / A+ / AA-
State Farm continues to be the largest bondholder
0
1
2
3
4
5
6
7
2020 2022 2024 2026 2028 2030 2032 2034 2036 2038 2040
$ millions
Series 2010 (BABs)
Series 2011
Series 2016
Total Debt Service (w/Subsidy)
Current Bondholders Outstanding Debt By Series
FirmHoldings
($000)1 State Farm $12,6352 BlackRock 5,7353 Fidelity 2,7904 Mercury Insurance 1,5605 First Trust Advisors 1,2356 Country Trust Bank 1,0007 Opus Investment Management 1,0008 New England Asset Management 8209 Invesco 750
10 AQS Asset Management 65011 GBU Financial Life 57512 Federated Mutual Insurance 50013 BMO Asset Management 29514 Associated Loggers Exchange 25015 Croatian Fraternal Union of America 24516 Workmen's Benefit Fund of the USA 10017 Breckinridge Capital Advisors 25
Source: As of July 1, 2020. Reflects publicly disclosed holders
Annual Debt Service
Issue Par Outstanding Callable Par Final Maturity Call Date Call ProvisionSeries 2010 (BABs) $17,345,000 $17,345,000 11/01/2030 Currently Make-WholeSeries 2011 $9,770,000 $1,695,000 11/01/2022 11/01/2021 100%Series 2016 $22,470,000 $18,870,000 11/01/2041 11/01/2026 100%Totals $49,585,000 $37,910,000
20
RBC Capital Markets7
Summary StatisticsSeries 2020A Par Amount $18,110,000Series 2020A Premium $3,313,080Total Sources $21,423,080DSRF Deposit $1,239,737Deposit to Project Fund $20,000,000All-in TIC 2.83%Arbitrage Yield 2.05%Average Coupon 4.03%Average Life (years) 18.90 years
Summary StatisticsSeries 2020A Par Amount $17,055,000Series 2020A Premium $3,120,291Total Sources $20,175,291DSRF Deposit $0Deposit to Project Fund $20,000,000All-in TIC 2.83%Arbitrage Yield 2.04%Average Coupon 4.03%Average Life (years) 18.90 years
Proposed New Money Bonds: $20 million Project Deposit
Project Fund: $20 million
Final maturity: 2045 (25 years)
Assumptions:
First principal amortization: 2031 First principal amortization: 2031
Case 1 with DSRF Case 2 without DSRF
Estimated Total Annual Debt Service Comparison
4% and 5% coupon structure
DSRF: with and without
Note: Preliminary analysis / subject to change – Rates as of June 23, 2020
012345678
2020 2022 2024 2026 2028 2030 2032 2034 2036 2038 2040 2042 2044
$ millions
Series 2010 (BABs) Series 2011 Series 2016 Case 1 Case 2 - Total Gross Debt Service
21
RBC Capital Markets8
Pricing ScheduleKey dates are shown below
Date Item
July 14 TuesdayCommission Meeting: Review bond structure
July/Aug Bond documents prepared/reviewed
July 28-29 Tues/Wed FOMC meeing
August 11 Tuesday Commission Meeting: Bond Resolution considered by Commission
August 13-14 Thurs/Friday Rating agency discussions
September 8 Tuesday Prelminary Official Statement posted/available to investors
September 16 Wednesday Price the Bonds/determine interest rates
September 29 Tuesday Bond issue closed; receive funds
Proposed Series 2020 BondsTimeline Overview
22
RBC Capital Markets9
Outstanding Bonds
SeriesOutstading
Par Consented%
ConsentedRefunding Consents
Revised % Consented
2010 (BABs) 17,345,000 2011 9,770,000 9,770,000 2016* 22,470,000 22,470,000 2020* New 17,500,000 17,500,000
Total 67,085,000 39,970,000 60% 9,770,000 74%* Consented
Refunding Components: Eliminating the DSRF New Bond Issues
Highly rated, essential service utilities, like the District, are no longer funding DSRFs
‒ Does not negatively impact credit ratings
‒ Investors do not require them
Refunding the Series 2011 Bonds allows this provision to take place
Requires consent of +66 2/3rds of current bondholders
Small cost associated with refunding: $79,000
Only the remaining bonds are subject to the DSRF (Series 2010 and Series 2016)
Avoids funding of the DSRF for the Series 2020 Bonds
Note: Preliminary analysis / subject to change – Rates as of June 23, 2020
1
Refunding the Series 2011 Bonds enables the District to eliminate the DSRF for new bonds
Refunding Mechanics:
• Issue refunding bonds to purchase escrow securities
• Escrow securities are placed with an agent and irrevocably pledged to pay prior bonds
• This allows for prior bonds to be defeased
• Once defeased, the bonds are no longer considered outstanding to the District
• The refunding bonds have replaced the old bonds
23
RBC Capital Markets10
Refunding Component: Reducing the DSRF Deposit
Note: Preliminary analysis / subject to change – Rates as of June 23, 2020
The remaining bonds continue to require a DSRF (Series 2010 and 2016)
Refunding a portion of these bonds reduces the required DSRF deposit
Current market conditions allow for efficient refunding of certain maturities to reduce the deposit
RBC analyzed all outstanding, individual maturities to determine most efficient candidates
Certain maturities of the Series 2016 Bonds can be refunded for little cost (< $235,000 to $310,000)
In total, the combined refunding candidates reduce the DSRF and avoid $1.3 million of additional DSRF deposit
2
Refunding a portion of the Series 2016 Bonds reduces the deposit to the DSRF
DSRF Reduction: $1,343,068
Current RequirementCash 1,107,865 On depositAdd'l Deposit 2,612,152 In 2021Total 3,720,017
Revised: Refund Series 2011 and partial Series 2016Cash 1,107,865 On depositAdd'l Deposit 1,269,084 In 2021Total 2,376,949
Refunding Mechanics:
• Issue refunding bonds to purchase escrow securities
• Escrow securities are placed with an agent and irrevocably pledged to pay prior bonds
• This allows for prior bonds to be defeased
• Once defeased, the bonds are no longer considered outstanding to the District
• The refunding bonds have replaced the old bonds
24
RBC Capital Markets11
Refunding Component: Levelizing Annual Debt Service
Note: Preliminary analysis / subject to change – Rates as of June 23, 2020
The current debt service profile has a significant step-down in 2022 and 2023
The Series 2011 Bonds have a short final maturity (2022)
‒ The refunding of these bonds, at little to no cost, allows for modest restructuring from 2020 to 2022
The result is levelized near-term debt service payment for smoother budgeting
Cost associated with this component is approximately $70,000 to $186,000
Unique opportunity to smooth upcoming payments
0
1
2
3
4
5
6
7
2020 2021 2022 2023 2024 2025 2026 2027 2028 2029 2030 2031 2032 2033 2034 2035 2036 2037 2038 2039 2040 2041
$ millions Series 2010 (BABs) Series 2011 Series 2016
3
Existing Annual Debt Service
25
RBC Capital Markets12
0
2
4
6
8
2020 2022 2024 2026 2028 2030 2032 2034 2036 2038 2040 2042 2044
$ millionsUnrefunded Debt Service Case 2: Refunding Debt Service New Money Debt Service Original DS
Results: Annual Debt Service Options
Note: Preliminary analysis / subject to change – Rates as of June 23, 2020
Case 2: With Smoothing of Debt Service
Base Case
0
2
4
6
8
2020 2022 2024 2026 2028 2030 2032 2034 2036 2038 2040 2042 2044
$ millions
Unrefunded Debt Service Refunding Debt Service New Money Debt Service Original DS
26
RBC Capital Markets13
Disclaimer (USA Municipal Finance)
RBC Capital Markets, LLC (“RBCCM”), seeks to serve as an underwriter on a future transaction and not as a financial advisor or municipal advisor. The information provided is for discussion purposes only in anticipation of being engaged to serve as an underwriter. The primary role of an underwriter is to purchase securities with a view to distribution in an arm’s-length commercial transaction with the issuer. The underwriter has financial and other interests that differ from those of the Issuer. RBCCM is not recommending an action to you as the municipal entity or obligated person. RBCCM is not acting as an advisor to you and does not owe a fiduciary duty pursuant to Section 15B of the Exchange Act to you with respect to the information and material contained in this communication. RBCCM is acting for its own interests. You should discuss any information and material contained in this communication with any and all internal or external advisors and experts that you deem appropriate before acting on this information or material.Disclaimer:This presentation was prepared exclusively for the benefit of and internal use by the recipient for the purpose of considering the transaction or transactions contemplated herein. This presentation is confidential and proprietary to RBC Capital Markets, LLC (“RBCCM”) and may not be disclosed, reproduced, distributed or used for any other purpose by the recipient without RBCCM’s express written consent. By acceptance of these materials, and notwithstanding any other express or implied agreement, arrangement, or understanding to the contrary, RBCCM, its affiliates and the recipient agree that the recipient (and its employees, representatives, and other agents) may disclose to any and all persons, without limitation of any kind from the commencement of discussions, the tax treatment, structure or strategy of the transaction and any fact that may be relevant to understanding such treatment, structure or strategy, and all materials of any kind (including opinions or other tax analyses) that are provided to the recipient relating to such tax treatment, structure, or strategy.The information and any analyses contained in this presentation are taken from, or based upon, information obtained from the recipient or from publicly available sources, the completeness and accuracy of which has not been independently verified, and cannot be assured by RBCCM. The information and any analyses in these materials reflect prevailing conditions and RBCCM’s views as of this date, all of which are subject to change. To the extent projections and financial analyses are set forth herein, they may be based on estimated financial performance prepared by or in consultation with the recipient and are intended only to suggest reasonable ranges of results. The printed presentation is incomplete without reference to the oral presentation or other written materials that supplement it.IRS Circular 230 Disclosure: RBCCM and its affiliates do not provide tax advice and nothing contained herein should be construed as tax advice. Any discussion of U.S. tax matters contained herein (including any attachments) (i) was not intended or written to be used, and cannot be used, by you for the purpose of avoiding tax penalties; and (ii) was written in connection with the promotion or marketing of the matters addressed herein. Accordingly, you should seek advice based upon your particular circumstances from an independent tax advisor.
27
PUBLIC UTILITY DISTRICT NO. 1 OF BENTON CO., WA.TREASURER'S REPORT TO COMMISSION FOR JUNE 2020
Jul 6, 2020
Final
`
REVENUE FUND: RECEIPTS DISBURSEMENTS BALANCE
06/01/20 Cash Balance 2,152,909.37$ Collections 11,738,769.80$
Investments Matured 6,012,326.36
Miscellaneous - BAB's Subsidy - Transfer from Debt Service Fund -
EFT Taxes 717,431.39$
Checks Paid 659,358.77 Debt Service to Unrestricted - Debt Service to Restricted 512,326.36 Investments Purchased 5,510,774.16
Deferred Compensation 122,168.91
Department of Retirement Systems 235,199.21
Purchase Inv - Special Fund-Construction Funds - Purchased Power 7,004,322.17
Direct Deposit - Payroll & AP 2,257,080.55
Credit Card Fees 29,154.77 Miscellaneous - BPA Broadband Pmt. and DOR License Renewal 569.80
Sub-total 17,751,096.16$ 17,048,386.09$ 06/30/20 Cash Balance 2,855,619.44$
Balance Balance
Investment 06/01/20 Purchased Matured LGIP Interest 06/30/20
Activity $34,712,719.85 6,012,326.36 6,012,326.36 $10,774.16 $34,723,494.01
Balance Balance
Check 06/01/20 Issued Redeemed Cancelled* 06/30/20
Activity $32,087.03 $654,812.74 $659,358.77 $325.00 $27,216.00
Unrestricted Reserves: 06/01/20 06/30/20 Change
Minimum Operating Reserves (90 DCOH) Incl. RSA 35,683,380.00$ 35,509,410.00$ (173,970.00)$ Designated Reserves (Bond Insurance Replacement) 2,612,152.17 2,612,152.17 - Designated Reserves (Customer Deposits Account) 1,900,000.00 1,900,000.00 -
Designated Reserves (Power Market Volatility Account) 1,229,168.70 1,229,168.70 -
Designated Reserves (Special Capital Account) - - -
Undesignated Reserves (DCOH -20 days) (8,138,171.15) (7,763,043.28) 375,127.87 Unrestricted Reserves Total 33,286,529.72 33,487,687.59 201,157.87
DCOH - Beginning and Ending of Month 84 85DCOH - Year-end Projection ($38.3M) 96 97
Restricted Reserves:Bond Reserve Account 1,107,865.13$ 1,107,865.13$ -
Bond Redemption Accounts 2,471,234.37 2,983,560.74 512,326.36
Restricted Reserves Total 3,579,099.50 4,091,425.87 512,326.36
TOTAL RESERVES 36,865,629.22$ 37,579,113.46$ 713,484.23$
(1) RSA (Rate Stabilization Account): $7,500,000.00
(2) Undesignated Reserves are periodically reviewed to reallocate to the Designated Reserve accounts
(3) Year-end DCOH projection includes actuals through June and no impacts related to weather or COVID-19 past June.
Prepared by:__________________________________ Certified by:____________________________________
Keith Mercer, Treasurer Jon Meyer, Auditor
(2)
(1)
(3)
28
CASH & INVESTMENTS SUMMARY Average Weighted Yield 0.371%
as of June 30, 2020
Maturity Investment Financial Call Investment
Date Instrument Institution Provisions Yield Date Amount
TOTAL SECURITIES -
Daily LGIP** N/A 0.371% Varied 34,723,494
TOTAL INVESTMENTS 34,723,494
CASH 2,855,616
* Held in custody at Wells Fargo Bank TOTAL CASH & INVESTMENTS $ 37,579,111** Local Government Investment Pool
Average Days to Maturity 0
Investment Portfolio
LGIP FHLB FNMA FHLMC FFCB Cash
0.00%
0.50%
1.00%
1.50%
2.00%
2.50%
3.00%
Historical LGIP Rate
0.0
1.0
2.0
3.0
1 mo 3 mo 6 mo 1 yr 2 yr 3 yr 5 yr
Pe
rce
nta
ge
Daily Treasury Yield Curve 6/30/2020 6/30/2019 6/30/2018
Source: http://www.ustreas.gov/offices/domestic-finance/debt-management/interest-rate/yield.shtml
J F M A M J J A S O N D J F M A M J J A S O N D J F M A M J J A S O N D
- -
2020 20222021
29
Unrestricted Reserves and Days Cash on Hand (DCOH)
$35.7
$2.6 $1.9 $1.2 $- $-
90 DCOH
7 DCOH 5 DCOH 3 DCOH
0 DCOH 0 DCOH
$-
$5.0
$10.0
$15.0
$20.0
$25.0
$30.0
$35.0
$40.0
MinimumOperatingReserves
Bond InsuranceReplacement
CustomerDeposits
Power MarketVolatility
Special Capital UndesignatedReserves
$ M
illio
ns
Unrestricted Reserves as of January 1, 2020 Treasurer's Report*
$35.5
$2.6 $1.9 $1.2 $-
$(7.8)
90 DCOH
7 DCOH 5 DCOH 3 DCOH 0 DCOH
(20) DCOH
$(10.0)
$(5.0)
$-
$5.0
$10.0
$15.0
$20.0
$25.0
$30.0
$35.0
$40.0
MinimumOperatingReserves
Bond InsuranceReplacement
Customer Deposits Power MarketVolatility
Special Capital UndesignatedReserves
$ M
illio
ns
Unrestricted Reservesas of June 30, 2020
Total Reserves: $41.4M Estimated 2020 $ per 1 DCOH: $397k
Total DCOH: 105
*On January 14, 2020, the Commission approved redistributing the Undesignated Reserves to Designated Reserve accounts
forecast
#1
#2
$37.7 $38.5 $37.1 $37.1 $38.1 $38.3
95
DC
OH
98
DC
OH
93
DC
OH
93
DC
OH
96
DC
OH
97
DC
OH
0
20
40
60
80
100
120
140
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
$0.0
$5.0
$10.0
$15.0
$20.0
$25.0
$30.0
$35.0
$40.0
$45.0
Day
s C
ash
on
Han
d (
DC
OH
)
Un
rest
rict
ed
Re
serv
es
$ M
illio
ns
2020 Forecasted Year-End Unrestricted Reserve Balance and DCOH by Month
#3
7/6/2020
DCOH calculation from current 2020
Total DCOH: 85Estimated 2020 $ per 1 DCOH: $395k Total Reserves: $33.5M
30
Note: Starting in 2019, the Privilege Tax due date changed to February. Prior to 2019, the Privilege Tax due date and payment was in May. Privilege
Tax payments were moved to February for 2018 - 2016 for comparison purposes. Also, in 2016 the $15M received from issuing bonds in October was
removed for comparison purposes.
$(15.0)
$(13.0)
$(11.0)
$(9.0)
$(7.0)
$(5.0)
$(3.0)
$(1.0)
$1.0
$3.0
$5.0
Start ofYear
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
Mill
ion
sCumulative Unrestricted Reserves by End of Month by Year
2016 2017 2018 2019 2020
23
4
1
31
as of Jun 30,2020
CounterPartyUnsecured
CreditGuaranty Collateral Total Credit
Credit
Available
%
AvailableBilled Unbilled
MTM
Exposure
Total
Exposure
American Electric Power Service Corporation 825,000 0 0 825,000 825,000 50% 0 0 0 0
WSPP 0 0 0 825,000 825,000 100% 0 0 0 0
AAA 825,000 0 0 825,000 0 0% 0 0 0 0
Arizona Public Service Company 2,250,000 0 0 2,250,000 2,250,000 50% 0 0 0 0
WSPP 0 0 0 2,250,000 2,250,000 100% 0 0 0 0
AAA 2,250,000 0 0 2,250,000 0 0% 0 0 0 0
Avista Corporation 225,000 0 0 225,000 225,000 50% 0 0 0 0
WSPP 0 0 0 225,000 225,000 100% 0 0 0 0
AAA 225,000 0 0 225,000 0 0% 0 0 0 0
BP Energy Company 0 2,900,000 0 2,900,000 5,872,183 67% 0 22,022 (58,114) (36,091)
ISDA 0 0 0 2,900,000 2,936,091 101% 0 22,022 (58,114) (36,091)
WSPP 0 0 0 2,900,000 2,936,091 101% 0 0 0 0
AAA 0 2,900,000 0 2,900,000 0 0% 0 0 0 0
Citigroup Energy Inc. 0 2,250,000 0 2,250,000 3,197,444 47% 0 169,358 481,919 651,278
ISDA w/ Pwr Anx 0 0 0 2,250,000 1,598,722 71% 0 169,358 481,919 651,278
WSPP 0 0 0 2,250,000 1,598,722 71% 0 0 0 0
AAA 0 2,250,000 0 2,250,000 0 0% 0 0 0 0
City of Seattle, by and through its City Light Dept 2,250,000 0 0 2,250,000 2,250,000 50% 0 0 0 0
WSPP 0 0 0 2,250,000 2,250,000 100% 0 0 0 0
AAA 2,250,000 0 0 2,250,000 0 0% 0 0 0 0
Clatskanie People's Utility District 1,640,625 0 0 1,640,625 1,640,625 50% 0 0 0 0
WSPP 0 0 0 1,640,625 1,640,625 100% 0 0 0 0
AAA 1,640,625 0 0 1,640,625 0 0% 0 0 0 0
CP Energy Marketing (US) Inc. 0 2,000,000 0 2,000,000 2,000,000 50% 0 0 0 0
WSPP 0 0 0 2,000,000 2,000,000 100% 0 0 0 0
AAA 0 2,000,000 0 2,000,000 0 0% 0 0 0 0
EDF Trading North America, LLC 0 2,250,000 0 2,250,000 2,337,591 104% 0 (175,890) 88,299 (87,591)
ISDA w/ Pwr Anx 0 2,250,000 0 2,250,000 2,337,591 104% 0 (175,890) 88,299 (87,591)
AAA 0 0 0 0 0 0% 0 0 0 0
Emerald People's Utility District 2,250,000 0 0 2,250,000 2,250,000 50% 0 0 0 0
Transmission 0 0 0 2,250,000 2,250,000 100% 0 0 0 0
AAA 2,250,000 0 0 2,250,000 0 0% 0 0 0 0
Eugene Water & Electric Board 2,250,000 0 0 2,250,000 2,250,000 50% 0 0 0 0
WSPP 0 0 0 2,250,000 2,250,000 100% 0 0 0 0
AAA 2,250,000 0 0 2,250,000 0 0% 0 0 0 0
Exelon Generation Company, LLC 2,250,000 0 0 2,250,000 4,500,000 67% 0 0 0 0
ISDA 0 0 0 2,250,000 2,250,000 100% 0 0 0 0
WSPP 0 0 0 2,250,000 2,250,000 100% 0 0 0 0
AAA 2,250,000 0 0 2,250,000 0 0% 0 0 0 0
FortisBC Energy Inc. 225,000 0 0 225,000 225,000 50% 0 0 0 0
Gas EDI 0 0 0 225,000 225,000 100% 0 0 0 0
Credit Exposure Report: Public Utility District No. 1 of Benton County, Washington
Page 1 of 432
as of Jun 30,2020
CounterPartyUnsecured
CreditGuaranty Collateral Total Credit
Credit
Available
%
AvailableBilled Unbilled
MTM
Exposure
Total
Exposure
Credit Exposure Report: Public Utility District No. 1 of Benton County, Washington
AAA 225,000 0 0 225,000 0 0% 0 0 0 0
Grant County Public Utility District No. 2 2,250,000 0 0 2,250,000 2,250,000 50% 0 0 0 0
WSPP 0 0 0 2,250,000 2,250,000 100% 0 0 0 0
AAA 2,250,000 0 0 2,250,000 0 0% 0 0 0 0
Idaho Falls Power 1,265,625 0 0 1,265,625 1,265,625 50% 0 0 0 0
WSPP 0 0 0 1,265,625 1,265,625 100% 0 0 0 0
AAA 1,265,625 0 0 1,265,625 0 0% 0 0 0 0
Idaho Power Company 2,250,000 0 0 2,250,000 2,250,000 50% 0 0 0 0
WSPP 0 0 0 2,250,000 2,250,000 100% 0 0 0 0
AAA 2,250,000 0 0 2,250,000 0 0% 0 0 0 0
IGI Resources, Inc. 0 100,000 0 100,000 100,000 50% 0 0 0 0
Gas 0 0 0 100,000 100,000 100% 0 0 0 0
AAA 0 100,000 0 100,000 0 0% 0 0 0 0
J. Aron & Company LLC 0 2,250,000 0 2,250,000 2,250,000 50% 0 0 0 0
WSPP 0 0 0 2,250,000 2,250,000 100% 0 0 0 0
AAA 0 2,250,000 0 2,250,000 0 0% 0 0 0 0
Macquarie Energy, LLC 0 2,150,000 0 2,150,000 1,568,139 73% 0 (44,908) 626,769 581,861
ISDA w/ Pwr Anx 0 2,150,000 0 2,150,000 1,568,139 73% 0 (44,908) 626,769 581,861
AAA 0 0 0 0 0 0% 0 0 0 0
Morgan Stanley Capital Group Inc. 0 2,250,000 0 2,250,000 3,682,430 55% 0 (28,022) 436,807 408,785
ISDA 0 0 0 2,250,000 1,841,215 82% 0 (28,022) 436,807 408,785
WSPP 0 0 0 2,250,000 1,841,215 82% 0 0 0 0
AAA 0 2,250,000 0 2,250,000 0 0% 0 0 0 0
NorthWestern Corporation d/b/a NorthWestern Energy1,800,000 0 0 1,800,000 1,800,000 50% 0 0 0 0
WSPP 0 0 0 1,800,000 1,800,000 100% 0 0 0 0
AAA 1,800,000 0 0 1,800,000 0 0% 0 0 0 0
PacifiCorp 2,250,000 0 0 2,250,000 4,500,000 67% 0 0 0 0
Transmission 0 0 0 2,250,000 2,250,000 100% 0 0 0 0
WSPP 0 0 0 2,250,000 2,250,000 100% 0 0 0 0
AAA 2,250,000 0 0 2,250,000 0 0% 0 0 0 0
Portland General Electric Company 2,250,000 0 0 2,250,000 2,250,000 50% 0 0 0 0
WSPP 0 0 0 2,250,000 2,250,000 100% 0 0 0 0
AAA 2,250,000 0 0 2,250,000 0 0% 0 0 0 0
Powerex Corp. 0 1,950,000 0 1,950,000 5,850,000 75% 0 0 0 0
ISDA 0 0 0 1,950,000 1,950,000 100% 0 0 0 0
NAESB 0 0 0 1,950,000 1,950,000 100% 0 0 0 0
WSPP 0 0 0 1,950,000 1,950,000 100% 0 0 0 0
AAA 0 1,950,000 0 1,950,000 0 0% 0 0 0 0
Public Service Company of Colorado 1,258,125 0 0 1,258,125 1,258,125 50% 0 0 0 0
WSPP 0 0 0 1,258,125 1,258,125 100% 0 0 0 0
AAA 1,258,125 0 0 1,258,125 0 0% 0 0 0 0
Page 2 of 433
as of Jun 30,2020
CounterPartyUnsecured
CreditGuaranty Collateral Total Credit
Credit
Available
%
AvailableBilled Unbilled
MTM
Exposure
Total
Exposure
Credit Exposure Report: Public Utility District No. 1 of Benton County, Washington
Public Utility District No. 1 of Chelan County, Washington2,250,000 0 0 2,250,000 2,250,000 50% 0 0 0 0
WSPP 0 0 0 2,250,000 2,250,000 100% 0 0 0 0
AAA 2,250,000 0 0 2,250,000 0 0% 0 0 0 0
Public Utility District No. 1 of Clark County, Washington 2,250,000 0 0 2,250,000 2,250,000 50% 0 0 0 0
WSPP 0 0 0 2,250,000 2,250,000 100% 0 0 0 0
AAA 2,250,000 0 0 2,250,000 0 0% 0 0 0 0
Public Utility District No. 1 of Cowlitz County, Washington2,250,000 0 0 2,250,000 2,250,000 50% 0 0 0 0
WSPP 0 0 0 2,250,000 2,250,000 100% 0 0 0 0
AAA 2,250,000 0 0 2,250,000 0 0% 0 0 0 0
Public Utility District No. 1 of Franklin County, Washington2,250,000 0 0 2,250,000 4,500,000 67% 0 0 0 0
Transmission 0 0 0 2,250,000 2,250,000 100% 0 0 0 0
WSPP 0 0 0 2,250,000 2,250,000 100% 0 0 0 0
AAA 2,250,000 0 0 2,250,000 0 0% 0 0 0 0
Public Utility District No. 1 of Grays Harbor County, Washington2,250,000 0 0 2,250,000 4,500,000 67% 0 0 0 0
Transmission 0 0 0 2,250,000 2,250,000 100% 0 0 0 0
WSPP 0 0 0 2,250,000 2,250,000 100% 0 0 0 0
AAA 2,250,000 0 0 2,250,000 0 0% 0 0 0 0
Public Utility District No. 1 of Klickitat County, Washington2,203,125 0 0 2,203,125 6,609,375 75% 0 0 0 0
Power 0 0 0 2,203,125 2,203,125 100% 0 0 0 0
Transmission 0 0 0 2,203,125 2,203,125 100% 0 0 0 0
WSPP 0 0 0 2,203,125 2,203,125 100% 0 0 0 0
AAA 2,203,125 0 0 2,203,125 0 0% 0 0 0 0
Public Utility District No. 1 of Snohomish County 2,250,000 0 0 2,250,000 2,250,000 50% 0 0 0 0
WSPP 0 0 0 2,250,000 2,250,000 100% 0 0 0 0
AAA 2,250,000 0 0 2,250,000 0 0% 0 0 0 0
Public Utility District No. 3 of Mason County 1,453,125 0 0 1,453,125 1,452,616 50% 0 505 4 509
WSPP 0 0 0 1,453,125 1,452,616 100% 0 505 4 509
AAA 1,453,125 0 0 1,453,125 0 0% 0 0 0 0
Puget Sound Energy Inc. 2,100,000 0 0 2,100,000 4,200,000 67% 0 0 0 0
NAESB 0 0 0 2,100,000 2,100,000 100% 0 0 0 0
WSPP 0 0 0 2,100,000 2,100,000 100% 0 0 0 0
AAA 2,100,000 0 0 2,100,000 0 0% 0 0 0 0
Sacramento Municipal Utility District 2,250,000 0 0 2,250,000 2,250,000 50% 0 0 0 0
WSPP 0 0 0 2,250,000 2,250,000 100% 0 0 0 0
AAA 2,250,000 0 0 2,250,000 0 0% 0 0 0 0
Shell Energy North America (Canada), Inc. 100,000 0 0 100,000 100,000 50% 0 0 0 0
NAESB 0 0 0 100,000 100,000 100% 0 0 0 0
AAA 100,000 0 0 100,000 0 0% 0 0 0 0
Shell Energy North America (US), L.P. 1,283,750 0 0 1,283,750 2,567,500 67% 0 0 0 0
ISDA 0 0 0 1,283,750 1,283,750 100% 0 0 0 0
WSPP 0 0 0 1,283,750 1,283,750 100% 0 0 0 0
Page 3 of 434
as of Jun 30,2020
CounterPartyUnsecured
CreditGuaranty Collateral Total Credit
Credit
Available
%
AvailableBilled Unbilled
MTM
Exposure
Total
Exposure
Credit Exposure Report: Public Utility District No. 1 of Benton County, Washington
AAA 1,283,750 0 0 1,283,750 0 0% 0 0 0 0
Tacoma Power 2,250,000 0 0 2,250,000 4,500,000 67% 0 0 0 0
Transmission 0 0 0 2,250,000 2,250,000 100% 0 0 0 0
WSPP 0 0 0 2,250,000 2,250,000 100% 0 0 0 0
AAA 2,250,000 0 0 2,250,000 0 0% 0 0 0 0
Tenaska Marketing Ventures 0 1,875,000 0 1,875,000 1,875,000 50% 0 0 0 0
NAESB 0 0 0 1,875,000 1,875,000 100% 0 0 0 0
AAA 0 1,875,000 0 1,875,000 0 0% 0 0 0 0
Tenaska Power Services Company 0 1,875,000 0 1,875,000 3,750,000 67% 0 0 0 0
Transmission 0 0 0 1,875,000 1,875,000 100% 0 0 0 0
WSPP 0 0 0 1,875,000 1,875,000 100% 0 0 0 0
AAA 0 1,875,000 0 1,875,000 0 0% 0 0 0 0
The Energy Authority, Inc. 4,000,000 0 0 4,000,000 12,033,731 75% 0 (11,912) 669 (11,244)
Acct RMA 0 0 0 4,000,000 4,011,244 100% 0 (91,959) 200 (91,759)
Transmission 0 0 0 4,000,000 4,011,244 100% 0 0 0 0
WSPP 0 0 0 4,000,000 4,011,244 100% 0 80,047 469 80,516
AAA 4,000,000 0 0 4,000,000 0 0% 0 0 0 0
Page 4 of 435
95%
0% 0% 4% 0%0%
Benton PUD Credit Exposure by Sector as of June 30, 2020Bank $1,726,431 Integrated Oil & Gas Companies $0 IOU $13,665
IOU Affiliate $125 Marketer/Merchant $82,052 Muni/Coop $2,170
RTO $0
Benton's total exposure (principal and agent) is $1,824,443
36
78%
0%
1%
18%
1%0%
Benton PUD Credit Exposure by Sector as of May 31, 2020Bank $1,665,115 Integrated Oil & Gas Companies $0 IOU $41,634
IOU Affiliate $16,108 Marketer/Merchant $389,808 Muni/Coop $11,069
RTO $7,557
Benton's total exposure (principal and agent) is $2,131,290
37
PUBLIC UTILITY DISTRICT NO. 1 OF
BENTON COUNTY
Date: June 23, 2020 Time: 9:00 a.m. Place: Via MS Teams, per Proclamation No. 20-28 Attendees: Commissioners Hall, Bush and Sanders General Counsel Hultgrenn General Manager Dunn Assistant General Manager Hunter Director of Finance and Customer Services Meyer Director of Executive Administration Conover Director of IT and Broadband Services Folta Director of Power Management White Manager of Communications and Governmental Relations Henderson Manager of Risk Management and Treasury Operations Mercer Manager of Accounting Zirker Manager of Contracts & Purchasing Ochweri Manager of Customer Service McAloon Manager of Conservation & Renewable Energy Programs Johnson Manager of System Engineering Edwards Supervisor of Executive Administration/Clerk of the Board Manager Marshall Senior Engineer Scherer Commissioner Jeff Hall announced that Commissioner Lori Sanders would be a few minutes late in joining today’s commission meeting. The Pledge of Allegiance was given. Consent Agenda Motion by Barry Bush, seconded by Jeff Hall to approve the Consent Agenda as follows: a) Approving Commission Meeting Minutes of June 9, 2020. b) Approving Vouchers audited and certified by the auditing officer as required by RCW 42.24.080, and those expense reimbursement claims certified as required by RCW 42.24.090, have been recorded on a listing made available to the Commission. As of this date, the Commission does approve the following for payment: Accounts Payable: Automated Clearing House (DD) payments 80483-80499 80653-80672 in the total amount of $569,615.09, Checks & Customer Refund payments (CHK) 79205-79252 in the total amount of $142,100.05, Electronic Fund Transfer (WIRE) payments 5379-5393 in the total amount of $749,920.09; Residential
38
Conservation Rebates, Credits on Customer Accounts in the total amount of $260.00; Payroll, Direct Deposit 06/11/20 80500-80652 in the total amount of $394,882.24 for a grand total of $1,856,777.47. c) Approving work order 590993 to re-build the existing distribution line to a new 336.4 AAC overhead feeder along Sagebrush Road. d) Awarding Contract #20-21-18 for Southridge Substation Civil Construction to Palouse Power, LLC of Quincy, WA for the total amount of $687,543.72 plus Washington State sales tax in accordance with RCW 54.04.080. MOTION PASSED UNANIMOUSLY. State Auditor’s Office – Exit Conference for 2019 Accountability & Legal Compliance Audit Manager of Accounting introduced Markus Nelson, with the Washington State Auditor’s Office. Mr. Nelson reviewed the results of the 2019 accountability audit and stated the District was compliant with all areas of the audit. Mr. Nelson stated the District received a clean audit with no findings or management letter items. Mr. Nelson thanked District staff for their help throughout the audit process, while also working remotely. Commissioner Lori Sanders joined the commission meeting at 9:10 a.m. Report from Management General Manager: 1. General Manager reminded the Commissioners to review the commission message that will be included in the CAFR and provide any updates to Manager of Communications & Governmental Relations. A discussion was held regarding the letter the District drafted to send to the Governor as a follow up to the letter the Washington PUD Association (WPUDA) sent on behalf of its members. 2. An update was provided on a recent email the commissioners received from a customer regarding his concerns with a city of Kennewick contractor’s construction staging operation being conducted on a property adjacent to his home and to the District’s Highlands substation property. General Manager has communicated with City of Kennewick Officials and Benton PUD Operations staff have gone out to the property as well. Currently there is no concern from Benton PUD and City Officials are addressing other concerns related to this property with the customer. District staff will follow up with this customer. Director of Power Management: 1. Director provided an update on BPA’s integrated program review meeting that was held last week. BPA is currently proposing holding program costs flat for BP-22, which account for roughly half of BPA’s revenue requirement. 2. An update was provided on the District’s summer load position. A brief discussion was held on market power prices and summer temperatures.
39
Director of Finance and Customer Services: 1. Director reviewed the District’s May 2020 financial statements that are also posted on the District’s website. Director also reviewed graphs that were included in the commission packet which provided information on residential and general services, large general service, accounts receivables and customer service statistics. An update was given on District’s accounts receivables due to businesses not having staff in office to process payments as quickly as well as an update on State and Federal COVID-19 pledges that are being received on customer accounts. 2. Director reported on upcoming meetings District staff are having with other utilities and will return to a future commission meeting with updates on what other utilities are doing for customers during this pandemic. Director informed the Commission on letters that are being sent out to past due customers with assistance options that may be available to them. General Manager provided a staffing update. Commissioner Lori Sanders expressed her interest in joining the Sunrise Rotary and plans to join after the pandemic is over and in-person meetings are occurring. Business Agenda Wind Power and Clean Energy Policy Perspectives White Paper General Manager reviewed the Wind Power and Clean Energy Policy Perspectives White Paper that was also included in the commission packet. A discussion was held on the one-page Executive Summary and sections of the White Paper. Commissioner Lori Sanders suggested a possible rearrangement of the Executive Summary. All Commissioners agreed the Executive Summary should include talking points and that the District’s position could be more specific and clearer. A discussion was held regarding how the White Paper could be distributed and used once it is approved. General Manager will return to a future commission meeting after incorporating the ideas discussed during today’s meeting. At 10:43 a.m., Commission President Jeff Hall announced that the commission meeting would recess for 7 minutes. At 10:50 a.m., General Manager announced Commission President Jeff Hall was experiencing technical difficulties and the commission meeting would continue in recess for 5 minutes. At 10:55 a.m., Commission President Jeff Hall reconvened the commission meeting into regular open public session.
40
City of Kennewick Franchise Agreements for the Electrical City Ordinance 5872 (Contract #20-21-21) and Broadband Systems City Ordinance 5871 (Contract #20-46-09) General Manager and Director of IT and Broadband Services reviewed the proposed franchise agreements that were also included in the commission packet. These Ordinances allow the District to construct, maintain and operate the electrical and fiber optic systems within the City’s right of way and easements. Motion by Lori Sanders, seconded by Barry Bush authorizing the General Manager on behalf of the District to sign in substantially the form presented City Ordinance 5872 (Contract #20-21-21) and City Ordinance 5871 (Contract #20-46-09) with the City of Kennewick, to construct, maintain and operate the electrical and fiber optic systems; effective July 1, 2020 for five (5) years with the option to automatically renew for one (1) successive period for five (5) years. MOTION PASSED UNANIMOUSLY. Motion to Implement Long Term Payment Arrangements and Changes to Pay as You Go Director of Finance and Customer Services reviewed staff’s recommended motion to implement long-term payment arrangements and changes to Pay as You Go, as well as District communications to customers that would occur. Implementing long-term payment arrangements and changes to Pay as You Go provide an option to customers with past due amounts to maintain continuous service while paying past due amounts over a period of time. Discussions were held on circumstances that could occur for customers and options for customers who enroll in Pay as You Go. Director reviewed principles for long-term payment arrangements and Pay as you Go changes, informed the Commission of details that need to be further refined. Motion by Lori Sanders, seconded by Barry Bush directing staff to implement a long-term payment arrangement program for customers and changes to Pay as You Go in accordance with the principles in Attachment 1. MOTION PASSED UNANIMOUSLY. Authorizing General Manager to proceed with developing plans to issue $20 million in bonds in 2020 Director of Finance and Customer Services reviewed staff’s recommendation to issue bonds that would accomplish the following objectives; maintain the strategic capital program to develop a 21st century power grid, maintain adequate financial metrics and credit rating, be well positioned for anticipated continued power market volatility as the region struggles with replacing capacity from closure of coal plants, and remove the need for near-term rate increase during a time of economic downturn. Director informed the Commission that approval of this motion authorizes the General Manger to direct staff to develop plans to issue $20 million in bonds in 2020 as well as evaluate the potential for refinancing existing bonds. This motion is not an approval to issue bonds. Staff
41
will return to a future commission meeting with a recommended Resolution for adoption that would allow for the District to issue bonds. Motion by Lori Sanders, seconded by Barry Bush directing the General Manager, on behalf of the District to develop plans to issue $20 million in bonds in 2020, and review other refinancing opportunities of existing bonds. The actual bond issue will require subsequent Board approval. MOTION PASSED UNANIMOUSLY. Resolution No. 2547, Providing for the Reimbursement of Certain Expenditures Out of the Issuance and Sale of Reimbursement Bonds Director of Finance and Customer Services reviewed the recommended Resolution that would allow capital expenditures incurred 60 days prior to the date of this resolution to be reimbursed by the proceeds of any new money revenue bonds per IRS regulations. This resolution provides the District flexibility if bonds are issued but does not give approval to issue bonds nor does it obligate the District to issue bonds. Motion by Lori Sanders, seconded by Barry Bush adopting Resolution No. 2547, providing for the reimbursement of certain expenditures out of the issuance and sale of reimbursement bonds. MOTION PASSED UNANIMOUSLY. Future Planning Commissioner Lori Sanders informed the Commission that she would not be able to attend in-person commission meetings in July. Meeting Reports Commissioners Jeff Hall and Barry Bush virtually attended the WPUDA Board of Directors meeting. Commissioner Lori Sanders reported on her recent virtual attendance of a Benton County Council of Governments board meeting. Hearing no objection, Commission President Jeff Hall adjourned the Commission Meeting at 11:29 a.m. ______________________________ Jeffrey D. Hall, President ATTEST: ______________________________ Barry A. Bush, Secretary
42
Type of Payment Starting # Ending # Page # Amount
Accounts Payable:
Automated Clearing House (DD) Payments 80673 - 80714 1 - 4
80865 - 80905 5 - 8
Checks & Customer Refund Payments (CHK) 79253 - 79376 9 - 16
650,823.31$
Electronic Fund Transfer (WIRE) Payments 5394 - 5416 17
7,573,303.59$
Residential Conservation Rebates:
Credits on Customer Accounts
18 1,530.00$
Purchase Card Detail:
Payroll:
Direct Deposit - 06/25/20 80715 - 80864 351,631.28$
TOTAL 9,809,750.76$
Void DD
Void Checks 9 325.00$
Void Wires
______________________________________________
Jon L. Meyer, Auditor Date
Reviewed by: Approved by:
____________________________________ ______________________________________________
Rick Dunn, General Manager
______________________________________________
______________________________________________
PAYMENT APPROVAL
July 14, 2020
The vouchers presented on this Payment Approval Report for approval by the Board of Commissioners have been audited and certified by
the auditing officer as required by RCW 42.24.080, and those expense reimbursement claims by officers and employees have been certified
as required by RCW 42.24.090.
June 2020
1,232,462.58$
Jeffrey D. Hall, President
Lori Kays-Sanders, Vice-President
Barry A. Bush, Secretary
I, the undersigned Auditor of Public Utility District No. 1 of Benton County, do hereby certify under penalty of perjury that the materials have
been furnished, the services rendered, or the labor performed as described, or that any advance payment is due and payable pursuant to a
contract or is available as an option for full or partial fulfillment of a contractual obligation, and that the claims identified in this report are
just, due and unpaid obligations against the District and that I am authorized to authenticate and certify to said claims.
43
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Accounts PayableCheck Register
BENTON COUNTY PUD NO. 1
06/15/2020 To 07/05/2020Bank Account: 1 - Benton PUD ACH/Wire
Check /Tran Date
PmtType AmountVendor NameVendor Reference
DD80673 06/17/2020 10659 ABBA TECHNOLOGIES, INC. Sotware maintenance/renewel 4,068.73
DD80674 06/17/2020 475 ABM JANITORIAL SERVICES Janitorial Svc 3,879.39Janitorial Svc 4,704.27Janitorial Svc 1,424.36
Total for Check/Tran - 80674: 10,008.02
DD80675 06/17/2020 963 ANIXTER INC. Elbows 14,769.60switch 9,749.02
Total for Check/Tran - 80675: 24,518.62
DD80676 06/17/2020 811 AUS WEST LOCKBOX Weekly Svc 44.24Weekly Svc 40.61Weekly Svc 30.52Weekly Svc 36.95weekly svc 44.24weekly svc 40.61weekly svc 30.52weekly svc 36.95
Total for Check/Tran - 80676: 304.64
DD80677 06/17/2020 3347 CANON BUSINESS SOLUTIONS, INC. Monthly Billings 73.73Monthly Billing 28.08Monthly Billing 6.50
Total for Check/Tran - 80677: 108.31
DD80678 06/17/2020 2680 CO-ENERGY Fuel Svc 780.61
DD80679 06/17/2020 2972 COMPUNET, INC. Software Support/License 5,547.02
DD80680 06/17/2020 57 CONSOLIDATED ELECTRICAL DISTRIB Coupling 576.67conduit 8,294.25
Total for Check/Tran - 80680: 8,870.92
DD80681 06/17/2020 1897 CONTROL SOLUTIONS NORTHWEST IN troubleshooting server issues 135.76Chiller Start Up 1,350.66
/pro/rpttemplate/acct/2.47.1/ap/AP_CHK_REGISTER.xml.rpt51204 44
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Accounts PayableCheck Register
BENTON COUNTY PUD NO. 1
06/15/2020 To 07/05/2020Bank Account: 1 - Benton PUD ACH/Wire
Check /Tran Date
PmtType AmountVendor NameVendor Reference
Total for Check/Tran - 80681: 1,486.42
DD80682 06/17/2020 3167 COOPERATIVE RESPONSE CENTER, INC Multispeak OMS/CRCLink Single User 9,899.83
DD80683 06/17/2020 339 DELL MARKETING CORP Computers 5,895.48
DD80684 06/17/2020 10134 END 2 END TECHNOLOGIES, LLC radios 12,679.05radios -1,004.05
Total for Check/Tran - 80684: 11,675.00
DD80685 06/17/2020 3130 GDS ASSOCIATES, INC. PSA 342.50
DD80686 06/17/2020 79 GENERAL PACIFIC, INC. tape 1,355.33
DD80687 06/17/2020 3969 GPS INSIGHT, LLC Device Monitoring 2,036.59
DD80688 06/17/2020 724 HERITAGE PROFESSIONAL LANDSCAPI Landscaping Svc 1,597.51Landscaping Svc 270.40Landscaping Svc 290.08Landscaping Svc 377.10Landscaping Svc 979.02Landscaping Svc 320.12Landscaping Svc 928.26Landscaping Svc 415.47
Total for Check/Tran - 80688: 5,177.96
DD80689 06/17/2020 10662 HIGH VOLTAGE INC. Hipot meter/safaety switch -717.76Hipot meter/safaety switch 9,063.76
Total for Check/Tran - 80689: 8,346.00
DD80690 06/17/2020 990 INSIGHT PUBLIC SECTOR INC. Software License 531.39
DD80691 06/17/2020 1632 INTERCONTINENTAL EXCHANGE, INC. EConfirm Charges 5/20 114.00
DD80692 06/17/2020 3154 IVOXY CONSULTING, LLC Horizon Architecture Planning Svc 6,600.00
DD80693 06/17/2020 214 JACOBS & RHODES REEP 1,100.00
DD80694 06/17/2020 296 JOB'S NURSERY plants/shrubs 186.40
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Accounts PayableCheck Register
BENTON COUNTY PUD NO. 1
06/15/2020 To 07/05/2020Bank Account: 1 - Benton PUD ACH/Wire
Check /Tran Date
PmtType AmountVendor NameVendor Reference
DD80695 06/17/2020 103 KENNEWICK, CITY OF Occupation Tax 05/20 342,039.12
DD80696 06/17/2020 103 KENNEWICK, CITY OF Monthly billing 203.01Monthly Billing 302.84Monthly Billilng 369.36Monthly Billing 194.89Monthly billing 395.09
Total for Check/Tran - 80696: 1,465.19
DD80697 06/17/2020 2027 KUFFEL, HULTGRENN, KLASHKE AND Professional Svc 3,335.16
DD80698 06/17/2020 3644 LOOMIS Safepoint Svc 626.94Safepoint Svc 321.58
Total for Check/Tran - 80698: 948.52
DD80699 06/17/2020 3430 JESSICA MARSHALL IIMC Training 50.00
DD80700 06/17/2020 10563 MESSAGE TECHNOLOGIES, INC. IVR Svc 4,370.33
DD80701 06/17/2020 3821 NISC Software Lic-IVUE Mapwise 7,760.12Software Lic-IVUE Mapwise 2,299.29Software Lic-IVUE Mapwise 3,448.94Software Lic-IVUE Mapwise 15,232.81envelopes/mail svc/postage/data svc 30,429.31Postage/Online Payments 393.09Postage/Online Payments 385.54
Total for Check/Tran - 80701: 59,949.10
DD80702 06/17/2020 919 NOANET 1,460.002,131.00
15,376.8361,507.32
114,739.001,500.001,000.00
51204 /pro/rpttemplate/acct/2.47.1/ap/AP_CHK_REGISTER.xml.rpt
Bombing Range Rd Reconstruction EngBerrian Metering Tap EngLOC Draw #2Broadband BillingBroadband BillingFranklin POPKenn Verizon
46
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Accounts PayableCheck Register
BENTON COUNTY PUD NO. 1
06/15/2020 To 07/05/2020Bank Account: 1 - Benton PUD ACH/Wire
Check /Tran Date
PmtType AmountVendor NameVendor Reference
Paterson Metering Tap eng 1,500.00repairs - richland 1,732.29repairs - Richland 4,943.41
Total for Check/Tran - 80702: 205,889.85
DD80703 06/17/2020 3407 NRC ENVIRONMENTAL SERVICES INC. 2,838.37
DD80704 06/17/2020 3162 ONLINE INFORMATION SERVICES, INC. Online Utility Exchange -109.59Online Utility Exchange 1,383.89
Total for Check/Tran - 80704: 1,274.30
DD80705 06/17/2020 10035 PACIFIC POLE INSPECTION LLC 27,570.20
DD80706 06/17/2020 585 PARADISE BOTTLED WATER CO. Monthly Billing 187.66
DD80707 06/17/2020 1241 PARAMOUNT COMMUNICATIONS, INC. Momentum Telecom 162.90Momentum Telecom 245.44Momentum Telecom 22,742.14
Total for Check/Tran - 80707: 23,150.48
DD80708 06/17/2020 146 S&C ELECTRIC COMPANY Anchor bolt kit 249.78
DD80709 06/17/2020 2154 SENSUS USA, INC. SAAS Monthly Fee 7,645.84
DD80710 06/17/2020 1369 UNITED SALES ASSOCIATES, INC. batteries 7,133.63
DD80711 06/17/2020 10154 US PAYMENTS, LLC Kiosk Processing/Transaction 1,624.60Kiosk Processing/Transaction 1,440.00
Total for Check/Tran - 80711: 3,064.60
DD80712 06/17/2020 272 UTILITIES UNDERGROUND LOCATION Excavations Svc 984.27
DD80713 06/17/2020 205 WASHINGTON STATE AUDITOR'S OFFI Auditing Svc 3,924.57Energy Independence Attestation Audit 5,281.77
Total for Check/Tran - 80713: 9,206.34
DD80714 06/17/2020 182 WESCO DISTRIBUTION Wire 3,464.34wire 2,489.63
Total for Check/Tran - 80714: 5,953.97/pro/rpttemplate/acct/2.47.1/ap/AP_CHK_REGISTER.xml.rpt51204
Fire Guard Paint Application
47
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Accounts PayableCheck Register
BENTON COUNTY PUD NO. 1
06/15/2020 To 07/05/2020Bank Account: 1 - Benton PUD ACH/Wire
Check /Tran Date
PmtType AmountVendor NameVendor Reference
DD80865 06/24/2020 2872 A W REHN & ASSOC COBRA 25.00
DD80866 06/24/2020 1736 A W REHN & ASSOCIATES,INC. Flex Spending Dependent Care 384.62Flex Spending Health Care 1,902.48
Total for Check/Tran - 80866: 2,287.10
DD80867 06/24/2020 963 ANIXTER INC. material 3,773.85
DD80868 06/24/2020 811 AUS WEST LOCKBOX weekly svc 44.24weekly svc 40.61weekly svc 30.52weekly svc 36.95
Total for Check/Tran - 80868: 152.32
DD80869 06/24/2020 3347 CANON BUSINESS SOLUTIONS, INC. Monthly Billing 1.84
DD80870 06/24/2020 2972 COMPUNET, INC. Software/Support 3,698.52
DD80871 06/24/2020 75 FRANKLIN PUD CWPU 2,186.91
DD80872 06/24/2020 2675 G & W ELECTRIC COMPANY Sectionalizer Diamond Back 50,042.88Sectionalizer Diamond Back -3,962.88
Total for Check/Tran - 80872: 46,080.00
DD80873 06/24/2020 79 GENERAL PACIFIC, INC. Material 473.26fiber 5,098.93
Total for Check/Tran - 80873: 5,572.19
DD80874 06/24/2020 10142 GROWING FORWARD SERVICES Leadership Training 4,480.00
DD80875 06/24/2020 10420 HEALTH INVEST HRA TRUST Employer Monthly Fees 5/1/20-5/31/20 28.40
DD80876 06/24/2020 103 KENNEWICK, CITY OF Monthly billing 480.54
DD80877 06/24/2020 10055 LOGMEIN USA, INC. web Conferencing Svc 524.27
DD80878 06/24/2020 3343 MOSS ADAMS, LLP Auditing Svc 14,500.00
DD80879 06/24/2020 10474 DAWN STRINGER Facebook Ad - Power is Water 200.00
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Accounts PayableCheck Register
BENTON COUNTY PUD NO. 1
06/15/2020 To 07/05/2020Bank Account: 1 - Benton PUD ACH/Wire
Check /Tran Date
PmtType AmountVendor NameVendor Reference
DD80880 06/24/2020 10028 SYMETRA LIFE INSURANCE COMPANY Non-Barg Basic AD&D 171.36Non-Barg Basic Dep Life 102.06Non-Barg Basic Life 1,085.28Self Insured STD 369.75Basic AD&D 386.28Basic LIfe 1,249.01Supplemental AD&D - Child 5.64Supplemental AD&D - EE 359.40Supplemental AD&D - Spouse 197.40Supplemental Life - Child 64.35Supplemental Life - EE 2,926.30Supplemental Life - Spouse 633.95LTD - Buy-Up 880.00LTD - Core No Buy-Up 3,533.79LTD 88 12.28
Total for Check/Tran - 80880: 11,976.85
DD80881 06/24/2020 1048 UNITED WAY OF BENTON & FRANKLIN EE United Way Contribution 391.97
DD80882 06/24/2020 205 WASHINGTON STATE AUDITOR'S OFFI Endrgy Independence Attestation 836.94Endrgy Independence Attestation 147.03Accountability Audit 12,441.00
Total for Check/Tran - 80882: 13,424.97
DD80883 06/24/2020 10667 WBE TECHNOLOGIES LLC Rack Mount Fiber Panels 11,475.22
DD80884 06/24/2020 2791 WESTERN ELECTRICITY COORDINATIN Retired Recs 31.45
DD80885 07/01/2020 2872 A W REHN & ASSOC FSA Medical/Dep Cared Admin Fee 157.50
DD80886 07/01/2020 963 ANIXTER INC. material 6,340.85
DD80887 07/01/2020 811 AUS WEST LOCKBOX Weekly Svc 44.24weekly Svc 40.61Weekly Svc 30.52
/pro/rpttemplate/acct/2.47.1/ap/AP_CHK_REGISTER.xml.rpt51204 49
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Accounts PayableCheck Register
BENTON COUNTY PUD NO. 1
06/15/2020 To 07/05/2020Bank Account: 1 - Benton PUD ACH/Wire
Check /Tran Date
PmtType AmountVendor NameVendor Reference
Weekly Svc 36.95Total for Check/Tran - 80887: 152.32
DD80888 07/01/2020 613 CAMPBELL & COMPANY REEP 500.00
DD80889 07/01/2020 10033 COMPSYCH CORPORATION Guidance Resources 584.37
DD80890 07/01/2020 2972 COMPUNET, INC. Software License/Material 44.80Software License/Material 13,568.99Software License/Material 7,294.61
Total for Check/Tran - 80890: 20,908.40
DD80891 07/01/2020 10642 DAIKIN APPLIED AMERICAS, INC. Chiller repair 4,816.42
DD80892 07/01/2020 79 GENERAL PACIFIC, INC. material 3,567.90marker ball fiber 52.58tangent 15,188.80
Total for Check/Tran - 80892: 18,809.28
DD80893 07/01/2020 10499 INDUSTRIAL CONSTRUCTORS, INC. Chillier/boiler/Stucco bldg 4,075.00Construction of 9,775.00Chillier/Boiler Bldg 673.15Chillier/Boiler Bldg 2,143.33
Total for Check/Tran - 80893: 16,666.48
DD80894 07/01/2020 10660 IRBY ELECTRICAL UTILITIES DE AUTO 1/2 IN SHORT BAIL 201.67
DD80895 07/01/2020 214 JACOBS & RHODES REEP 500.00REEP 500.00
Total for Check/Tran - 80895: 1,000.00
DD80896 07/01/2020 3430 JESSICA MARSHALL IIMC Training 50.00
DD80897 07/01/2020 10651 MEINBERG USA, INC. SyncBox -198.66SyncBox 2,508.66
Total for Check/Tran - 80897: 2,310.00
DD80898 07/01/2020 111 MONARCH MACHINE & TOOL CO., INC. Aluminum plates 485.81
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Accounts PayableCheck Register
BENTON COUNTY PUD NO. 1
06/15/2020 To 07/05/2020Bank Account: 1 - Benton PUD ACH/Wire
Check /Tran Date
PmtType AmountVendor NameVendor Reference
DD80899 07/01/2020 1241 PARAMOUNT COMMUNICATIONS, INC. Tri City Orthodontics 162.90Tri City Orthodontics 6,401.56
Total for Check/Tran - 80899: 6,564.46
DD80900 07/01/2020 2632 PASCOR ATLANTIC CORPORATION Insulators 9,051.81Insulators -716.81
Total for Check/Tran - 80900: 8,335.00
DD80901 07/01/2020 3696 SUMMIT LAW GROUP, PLLC Professional Svc 330.00
DD80902 07/01/2020 155 THERMAL SUPPLY, INC. mateiral 7,902.11
DD80903 07/01/2020 1163 TYNDALE ENTERPRISES, INC. Clothing-Kile 287.95Clothing - Hartzell 109.20
Total for Check/Tran - 80903: 397.15
DD80904 07/01/2020 575 WELLS FARGO BANK EE Vision 122.33ER Vision 2,951.07EE Health 10,587.81ER Health 166,072.50EE Dental 677.58ER Dental 16,425.19
Total for Check/Tran - 80904: 196,836.48
DD80905 07/01/2020 182 WESCO DISTRIBUTION Splice 775.40auto splice 674.60Hardware Fitting 112.40
Total for Check/Tran - 80905: 1,562.40
Total Payments for Bank Account - 1 : (83) 1,232,462.58Total Voids for Bank Account - 1 : (0) 0.00
Total for Bank Account - 1 : (83) 1,232,462.58
/pro/rpttemplate/acct/2.47.1/ap/AP_CHK_REGISTER.xml.rpt51204 51
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Accounts PayableCheck Register
BENTON COUNTY PUD NO. 1
06/15/2020 To 07/05/2020Bank Account: 2 - BPUD Accounts Payable Warrants
Check /Tran Date
PmtType AmountVendor NameVendor Reference
CHK79230 06/03/2020 99999 DAVE A SITTMAN VOIDCredit Balance Refund 325.00
CHK79253 06/17/2020 3598 ALDEN SYSTEMS, INC. NotifyPro Subscription -344.00NotifyPro Subscription 4,344.00
Total for Check/Tran - 79253: 4,000.00
CHK79254 06/17/2020 215 ALLAN ELECTRIC AMI 564.72
CHK79255 06/17/2020 1372 ASSOCIATION OF WASHINGTON CITIES Membership Dues 500.00
CHK79256 06/17/2020 2425 AT&T MOBILITY Monthly billing 63.84
CHK79257 06/17/2020 436 BANK OF AMERICA LOC 10,111.11
CHK79258 06/17/2020 259 BENTON FRANKLIN COMMUNITY ACTI Helping Hands 1,367.05
CHK79259 06/17/2020 35 BENTON PUD - CUSTOMER ACCOUNT D Monthly Billing 719.69
CHK79260 06/17/2020 3172 BIG D'S CONSTRUCTION Gibbons Rd - Pole holes 1,148.45
CHK79261 06/17/2020 54 BNSF RAILWAY COMPANY Permit 275.00Permit 400.00Permit 100.00
Total for Check/Tran - 79261: 775.00
CHK79262 06/17/2020 3344 BOYD'S TREE SERVICE, LLC Tree Trimming Svc 7,940.48Tree Trimming svc 8,701.62Tree Trimming Svc 3,970.24
Total for Check/Tran - 79262: 20,612.34
CHK79263 06/17/2020 138 CCR - TRI-CITIES ,LLC Advertising 960.00Advertising 900.00Advertising 960.00
Total for Check/Tran - 79263: 2,820.00
CHK79264 06/17/2020 32 CITY OF BENTON CITY Occupation Tax 05/20 8,567.42
CHK79265 06/17/2020 2450 D HITTLE & ASSCOCIATES, INC. Southridge Substation 10,667.50Joint Use 1,600.00
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Accounts PayableCheck Register
BENTON COUNTY PUD NO. 1
06/15/2020 To 07/05/2020Bank Account: 2 - BPUD Accounts Payable Warrants
Check /Tran Date
PmtType AmountVendor NameVendor Reference
Total for Check/Tran - 79265: 12,267.50
CHK79266 06/17/2020 642 EVERGREEN FINANCIAL SERVICES, IN Debgt Collection Svc 31.79
CHK79267 06/17/2020 10169 FALCON SOFTWARE COMPANY, INC. Maintenance/Support 1,500.00
CHK79268 06/17/2020 10345 H&S STORAGE, LLC C0mmercial Energy Efficiency Prg 1,140.00
CHK79269 06/17/2020 310 MOON SECURITY SERVICES, INC. Monitoring Svc 288.87Monitoring Svc 109.69Monitoring Svc 79.28Monitoring Svc 79.28Monitoring Svc 79.28Monitoring Svc 131.95
Total for Check/Tran - 79269: 768.35
CHK79270 06/17/2020 2176 PACIFIC OFFICE AUTOMATION, INC. Monthly billing 25.10Monthly billing 9.32Monthly Billing 279.10
Total for Check/Tran - 79270: 313.52
CHK79271 06/17/2020 1661 PORTLAND BOLT Anchor Bolts 2,923.41
CHK79272 06/17/2020 135 PROSSER, CITY OF Occupation Tax 05/20 29,533.15
CHK79273 06/17/2020 1592 REESE CONCRETE PRODUCTS MFG. INC vault base/lid 19,005.00
CHK79274 06/17/2020 141 RICHLAND, CITY OF Occupation Tax 05/20 2,318.82
CHK79275 06/17/2020 10230 SMG-TRI CITIES, LLC Advertising 1,680.00Advertising 2,100.00Advertising 1,200.00
Total for Check/Tran - 79275: 4,980.00
CHK79276 06/17/2020 139 TOWNSQUARE MEDIA TRI CITIES Advertising 1,260.00Advertising 1,200.00Advertising 660.00
Total for Check/Tran - 79276: 3,120.00
/pro/rpttemplate/acct/2.47.1/ap/AP_CHK_REGISTER.xml.rpt51204 53
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Accounts PayableCheck Register
BENTON COUNTY PUD NO. 1
06/15/2020 To 07/05/2020Bank Account: 2 - BPUD Accounts Payable Warrants
Check /Tran Date
PmtType AmountVendor NameVendor Reference
CHK79277 06/17/2020 10669 TOYOTA OF TRI CITIES Commercial Energy Efficliency Prg 8,665.00
CHK79278 06/17/2020 3006 TRI-CITY GLASS, INC. REEP 1,412.36
CHK79279 06/17/2020 992 VERIZON NORTHWEST Monthly Billing 547.97
CHK79280 06/17/2020 100 WASTE MANAGEMENT OF WASHINGT Monthly billing 889.27Monthly billing 272.73Monthly Billing 510.98
Total for Check/Tran - 79280: 1,672.98
CHK79281 06/17/2020 99999 ADA B ADAMS Credit Balance Refund 246.58
CHK79282 06/17/2020 99999 ADA B ADAMS Credit Balance Refund 46.38
CHK79283 06/17/2020 99999 LUIS BELTRAN Credit Balance Refund 194.96
CHK79284 06/17/2020 99999 BRYCE BRAGG Credit Balance Refund 164.86
CHK79285 06/17/2020 99999 HELEN W BUESCHER Credit Balance Refund 38.17
CHK79286 06/17/2020 99999 ROXY DELORME Credit Balance Refund 34.28
CHK79287 06/17/2020 99999 STEVEN R EINAN Credit Balance Refund 400.00
CHK79288 06/17/2020 99999 DONA M ELWOOD Credit Balance Refund 250.00
CHK79289 06/17/2020 99999 JOHN L FRISCH Credit Balance Refund 142.30
CHK79290 06/17/2020 99999 HELEENE F GARZON Credit Balance Refund 109.01
CHK79291 06/17/2020 99999 TYLER S GOETSCH Credit Balance Refund 142.00
CHK79292 06/17/2020 99999 CONNIE L HEEP Credit Balance Refund 250.00
CHK79293 06/17/2020 99999 DEWAYNE L HETRICK Credit Balance Refund 300.00
CHK79294 06/17/2020 99999 VICTORIA HUEY Credit Balance Refund 47.70
CHK79295 06/17/2020 99999 BRADFORD K HUGGINS Credit Balance Refund 58.85
CHK79296 06/17/2020 99999 KEVIN R HULBERT Credit Balance Refund 306.24
CHK79297 06/17/2020 99999 NICOLE JACKSON-MILLER Credit Balance Refund 130.46
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Accounts PayableCheck Register
BENTON COUNTY PUD NO. 1
06/15/2020 To 07/05/2020Bank Account: 2 - BPUD Accounts Payable Warrants
Check /Tran Date
PmtType AmountVendor NameVendor Reference
CHK79298 06/17/2020 99999 ALMA JASHARI Credit Balance Refund 131.11
CHK79299 06/17/2020 99999 ANTONETTE JEWELL Credit Balance Refund 200.00
CHK79300 06/17/2020 99999 LOUIE J LOPEZ Credit Balance Refund 15.61
CHK79301 06/17/2020 99999 SHIRLEY F MARTIN Credit Balance Refund 300.00
CHK79302 06/17/2020 99999 ARAJETSY MARTINEZ Credit Balance Refund 29.45
CHK79303 06/17/2020 99999 CARMEN Z MATUS Credit Balance Refund 52.94
CHK79304 06/17/2020 99999 DAVID MCCARROLL Credit Balance Refund 82.61
CHK79305 06/17/2020 99999 NORMA JEAN MORELAND Credit Balance Refund 45.53
CHK79306 06/17/2020 99999 HOPE F MORRIS Credit Balance Refund 326.32
CHK79307 06/17/2020 99999 ASHLEY PENINGTON Credit Balance Refund 74.36
CHK79308 06/17/2020 99999 JACK L PIERCE SR Credit Balance Refund 116.22
CHK79309 06/17/2020 99999 PRATT FAMILY INVESTMENTS LLC Credit Balance Refund 325.77
CHK79310 06/17/2020 99999 CARLA REA Credit Balance Refund 31.29
CHK79311 06/17/2020 99999 RUBY A ROHDE Credit Balance Refund 148.67
CHK79312 06/17/2020 99999 ELIDA N SALDANA Credit Balance Refund 116.45
CHK79313 06/17/2020 99999 BRENDA SERVOSS Credit Balance Refund 116.60
CHK79314 06/17/2020 99999 EVELYN E SITTMAN Credit Balance Refund 325.00
CHK79315 06/17/2020 99999 LISA M STEELE Credit Balance Refund 536.30
CHK79316 06/17/2020 99999 DEANNA URIBE Credit Balance Refund 169.43
CHK79317 06/17/2020 99999 KELSEY VASQUEZ Credit Balance Refund 59.80
CHK79318 06/24/2020 54 BNSF RAILWAY COMPANY Permit - AS Cable Sewer Pipeline 250.00Permit-Anchor & Longitud Electric Line 100.00Permit- Electic Line Permit 650.00
Total for Check/Tran - 79318: 1,000.00
/pro/rpttemplate/acct/2.47.1/ap/AP_CHK_REGISTER.xml.rpt51204 55
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Accounts PayableCheck Register
BENTON COUNTY PUD NO. 1
06/15/2020 To 07/05/2020Bank Account: 2 - BPUD Accounts Payable Warrants
Check /Tran Date
PmtType AmountVendor NameVendor Reference
CHK79319 06/24/2020 3344 BOYD'S TREE SERVICE, LLC Tree Trimming Svc 7,421.36Tree Trimming Svc 6,333.56Tree Trimming Svc 1,389.58
Total for Check/Tran - 79319: 15,144.50
CHK79320 06/24/2020 10166 BYRNES OIL COMPANY, INC. Fuel Svc 3,210.71Fuel Svc 3,814.26
Total for Check/Tran - 79320: 7,024.97
CHK79321 06/24/2020 3520 CI INFORMATION MANAGEMENT Destruction Svc 567.00Storage Svc 68.98
Total for Check/Tran - 79321: 635.98
CHK79322 06/24/2020 3439 DJ'S ELECTRICAL, INC. Cable Replacement 23,379.93Cable Replacement 7,252.00Cable Replacement 211,366.62Joint Use-NESC Comploance 1,378.36Joint Use-NESC Comploance 574.31Joint Use-NESC Comploance 71,025.07
Total for Check/Tran - 79322: 314,976.29
CHK79323 06/24/2020 99 KIE SUPPLY CORP swab pipe 690.12BEND 90 PVC 2,678.08
Total for Check/Tran - 79323: 3,368.20
CHK79324 06/24/2020 10162 LINGUISTICA INTERNATIONAL, INC. Interpreting Svc 10.73
CHK79325 06/24/2020 2176 PACIFIC OFFICE AUTOMATION, INC. monthly billing 109.96
CHK79326 06/24/2020 379 PURMS JOINT SELF INSURANCE FUND AEGIS Public Officials Policy 18,144.84
CHK79327 06/24/2020 10212 QCL, INC. Drug Screening Svc 69.99
CHK79328 06/24/2020 3507 STORAGE BATTERY SYSTEMS LLC battery 1,521.05
CHK79329 06/24/2020 99999 MARIA A ALMONTE Credit Balance Refund 73.63
CHK79330 06/24/2020 99999 YADIRA ALVAREZ Credit Balance Refund 115.35
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Accounts PayableCheck Register
BENTON COUNTY PUD NO. 1
06/15/2020 To 07/05/2020Bank Account: 2 - BPUD Accounts Payable Warrants
Check /Tran Date
PmtType AmountVendor NameVendor Reference
CHK79331 06/24/2020 99999 JESSICA L ARCOS Credit Balance Refund 144.42
CHK79332 06/24/2020 99999 ANTJE BAHR Credit Balance Refund 65.48
CHK79333 06/24/2020 99999 RON BARNES Credit Balance Refund 30.27
CHK79334 06/24/2020 99999 NATALIE BELLOSO Credit Balance Refund 81.25
CHK79335 06/24/2020 99999 WILLETTA BETHEA Credit Balance Refund 124.22
CHK79336 06/24/2020 99999 JACOB M BREAUX Credit Balance Refund 138.61
CHK79337 06/24/2020 99999 BLAKE BUSHORE Credit Balance Refund 43.85
CHK79338 06/24/2020 99999 MARITZA CAMACHO Credit Balance Refund 32.89
CHK79339 06/24/2020 99999 ANDREA CARREON MALDONADO Credit Balance Refund 156.56
CHK79340 06/24/2020 99999 CHELSEA CHRISTENSEN Credit Balance Refund 126.94
CHK79341 06/24/2020 99999 SARAI DELATORRE Credit Balance Refund 124.32
CHK79342 06/24/2020 99999 CODY HARRINGTON Credit Balance Refund 148.72
CHK79343 06/24/2020 99999 DOMINIQUE A HERNANDEZ Credit Balance Refund 118.80
CHK79344 06/24/2020 99999 SARAH M JACKSON Credit Balance Refund 13.86
CHK79345 06/24/2020 99999 TREANNA JUDD Credit Balance Refund 57.95
CHK79346 06/24/2020 99999 PHILIP LIESSMANN Credit Balance Refund 51.06
CHK79347 06/24/2020 99999 GRACIELA MADRIGAL MERAZ Credit Balance Refund 35.46
CHK79348 06/24/2020 99999 HUU THACH NGUYEN Credit Balance Refund 17.95
CHK79349 06/24/2020 99999 CHEYENNE PARKS Credit Balance Refund 167.16
CHK79350 06/24/2020 99999 G C PAULSELL Credit Balance Refund 200.00
CHK79351 06/24/2020 99999 ANDREW G POMIAK Credit Balance Refund 152.96
CHK79352 06/24/2020 99999 ROBERT ELLIS POST 4 KENNEWICK Credit Balance Refund 129.99
CHK79353 06/24/2020 99999 MARIA I RODRIGUEZ-RUIZ Credit Balance Refund 22.78
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Accounts PayableCheck Register
BENTON COUNTY PUD NO. 1
06/15/2020 To 07/05/2020Bank Account: 2 - BPUD Accounts Payable Warrants
Check /Tran Date
PmtType AmountVendor NameVendor Reference
CHK79354 06/24/2020 99999 DEREK STRINGER Credit Balance Refund 41.33
CHK79355 06/24/2020 99999 TRUNG TRAN Credit Balance Refund 36.60
CHK79356 06/24/2020 99999 HALIE D ULREY Credit Balance Refund 148.35
CHK79357 06/24/2020 99999 CORRIE M VARGAS Credit Balance Refund 424.05
CHK79358 06/24/2020 99999 OSCAR VILLA Credit Balance Refund 134.07
CHK79359 06/24/2020 99999 JASON A ZOOK Credit Balance Refund 32.58
CHK79360 07/01/2020 2425 AT&T MOBILITY Monthly Billing 10.88
CHK79361 07/01/2020 35 BENTON PUD - CUSTOMER ACCOUNT D Monthly Billing 491.10
CHK79362 07/01/2020 3344 BOYD'S TREE SERVICE, LLC Tree Trimming Svc 7,940.48Tree Trimming Svc 5,373.86
Total for Check/Tran - 79362: 13,314.34
CHK79363 07/01/2020 166 CENTURYLINK Monthly Billing 452.12
CHK79364 07/01/2020 3029 DELTA HEATING & COOLING, INC. REEP 1,100.00
CHK79365 07/01/2020 3439 DJ'S ELECTRICAL, INC. Orchard View Underground Conduit 85,113.33
CHK79366 07/01/2020 10640 EXPRESS 24 HR PLUMBING & DRAIN, L Repair - admin mop sink 352.95
CHK79367 07/01/2020 10518 NORTHWEST RIVER PARTNERS Power is water Campaign 2020 27,956.00
CHK79368 07/01/2020 2176 PACIFIC OFFICE AUTOMATION, INC. Monthly Billing 9.35
CHK79369 07/01/2020 611 PAVEMENT SURFACE CONTROL Commercial Energy Efficiency Prg 3,524.00
CHK79370 07/01/2020 3054 PROFESSIONAL CREDIT SERVICE (PCS) Debt Collection Svc 59.80
CHK79371 07/01/2020 3506 SMART ENERGY CONSUMER COLLABO Membership Dues 2020-2021 2,500.00
CHK79372 07/01/2020 2699 TOTAL ENERGY MANAGEMENT & HVA REEP 1,100.00
CHK79373 07/01/2020 2699 TOTAL ENERGY MANAGEMENT & HVA REEP 1,100.00
CHK79374 07/01/2020 1397 UMATILLA ELECTRIC COOPERATIVE POle Contact 2020 21.90
CHK79375 07/01/2020 1304 US CELLULAR Monthly Billing 148.50/pro/rpttemplate/acct/2.47.1/ap/AP_CHK_REGISTER.xml.rpt51204 58
Page 1607/06/2020 8:21:43 AMRevision: 96739
Accounts PayableCheck Register
BENTON COUNTY PUD NO. 1
06/15/2020 To 07/05/2020Bank Account: 2 - BPUD Accounts Payable Warrants
Check /Tran Date
PmtType AmountVendor NameVendor Reference
CHK79376 07/01/2020 992 VERIZON NORTHWEST Monthly Billing 194.61Monthly Billing 147.00Monthly Billing 177.00Monthly Billing 181.97Monthly Billing 97.20Monthly Billing 58.57
Total for Check/Tran - 79376: 856.35
Total Payments for Bank Account - 2 : (124) 650,823.31Total Voids for Bank Account - 2 : (1) 325.00
Total for Bank Account - 2 : (125) 651,148.31
Grand Total for Payments : (207) 1,883,285.89Grand Total for Voids : (1) 325.00
Grand Total : 1,883,610.89(208)
/pro/rpttemplate/acct/2.47.1/ap/AP_CHK_REGISTER.xml.rpt51204 59
07/06/2020 11:55:24 AMRevision: 96739
Accounts PayableCheck Register
BENTON COUNTY PUD NO. 1
ALLBank Account: 1 - Benton PUD ACH/Wire
Check /Tran Date
PmtType AmountVendor NameVendor Reference
WIRE5394 06/15/2020 436 BANK OF AMERICA 1,549.57Banking Service FeesWIRE5396 06/15/2020 2570 THE ENERGY AUTHORITY, INC. 137,367.45Purchased PowerWIRE5397 06/19/2020 169 ENERGY NORTHWEST 162,684.38Purchased Power 7/20WIRE5398 06/19/2020 2902 WHITE CREEK WIND I, LLC 78,064.00Purchased Power 5/20WIRE5400 06/23/2020 1821 FREDERICKSON POWER L.P. 672,851.53Purchased Gas 5/20WIRE5401 06/23/2020 246 BONNEVILLE POWER ADMIN 4,720,089.00Purchased Power 5/20WIRE5402 06/01/2020 1680 MORGAN STANLEY 360.00Purchased Gas 4/20WIRE5404 06/25/2020 2205 UNITED STATES TREASURY 138,827.95Federal Income TaxWIRE5405 06/25/2020 1567 ICMA RETIREMENT CORP 60,174.93Deferred Comp - ERWIRE5406 06/25/2020 171 WASH STATE DEPT RETIREMENT SYS 112,306.76PERS - ERWIRE5407 06/25/2020 437 WASH STATE DEPT SUPPORT REGIST 925.24Garnishment - Child SupportWIRE5408 06/25/2020 246 BONNEVILLE POWER ADMIN 964,344.00Transmission Bill 5/20WIRE5409 06/25/2020 933 POWEREX CORPORATION 13,950.26Purchased GasWIRE5410 06/26/2020 424 WASH STATE DEPT REVENUE-EXCISE T 411,576.76Excise Tax 5/20WIRE5411 06/29/2020 246 BONNEVILLE POWER ADMIN 385.00Fiber LeaseWIRE5413 06/30/2020 10052 JACK HENRY & ASSOCIATES, INC. 563.10Merchant SvcWIRE5414 07/01/2020 2800 LL&P WIND ENERGY, INC. 60,079.12Purchased Power 5/20WIRE5415 07/03/2020 169 ENERGY NORTHWEST 33,146.08Purchased Power 5/20WIRE5416 07/03/2020 925 KLICKITAT COUNTY PUD 4,058.46TX White Crk/Rock Crk 5/20
Total Payments for Bank Account - 1 : (19) 7,573,303.59Total Voids for Bank Account - 1 : (0) 0.00
Total for Bank Account - 1 : (19) 7,573,303.59
Grand Total for Payments : (19) 7,573,303.59Grand Total for Voids : (0) 0.00
Grand Total : 7,573,303.59(19)
/pro/rpttemplate/acct/2.47.1/ap/AP_CHK_REGISTER.xml.rpt51204
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Date Customer Rebate Amount
06/19/2020 MARION GOODRICH 100.00$
06/19/2020 RUBEN NAVARRETE 100.00$
06/19/2020 XOIMARA COREA 100.00$
06/19/2020 ROGER J QUESNELL 100.00$
06/19/2020 JEFFREY LATENDRESSE 30.00$
07/01/2020 CHRISTINA SOMERO 500.00$
07/01/2020 LANAJ LEWIS 100.00$
07/01/2020 CHARLES DORENDORF 500.00$
1,530.00$
BENTON PUD - RESIDENTIAL CONSERVATION REBATE DETAIL
Rebate - Heat Pump Water Heater
Rebate - Smart Thermostat
Rebate - Heat Pump Water HeaterRebate - Energy Star Clothes Washer
Rebate - Smart Thermostat
Rebate - Smart Thermostat
Rebate - Smart Thermostat
Rebate - Smart Thermostat
Rebate Description
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Business Agenda
Second Reading
X Consent Agenda
Info Only/Possible Action
Info Only
COMMISSION MEETING AGENDA ITEM
Subject: Retired Equipment Surplus
Agenda Item No:
Meeting Date: July 14, 2020
Presented by: Michelle Ochweri Staff Presenting Item
Approved by (dept): Jon Meyer Director/Manager
Approved for Commission review:
Rick Dunn General Manager/Asst GM
Motion for Commission Consideration Motion to adopt Resolution No. 2548 declaring certain transformers surplus to District needs according to the laws of the State of Washington, Title 54, RCW 54.16.180, and authorizing the General Manager on behalf of the District to dispose of same. Background It is recommended that the attached list of District equipment to be declared surplus and no longer suitable for District use. These transformers have gone through the maintenance process, reviewed and been deemed no longer suitable for District use. Summary Unusable equipment is sent off site for disposal to a recycling facility that meets federal and state regulations. Fiscal Impact There is no cost to the District for this disposal activity.
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RESOLUTION NO. 2548 July 14, 2020 A RESOLUTION DECLARING CERTAIN EQUIPMENT SURPLUS TO DISTRICT NEEDS
WHEREAS, Public Utility District No. 1 of Benton County is desirous of disposing of certain surplus equipment that is unserviceable, obsolete, worn out, unfit, inadequate and/or no longer necessary, material to, and useful in its operations, and
WHEREAS, the laws of the State of Washington, Title 54, Revised Code of Washington, Chapter 54 Section 16.180, provided the necessary authority for the District to dispose of said equipment, Now, Therefore,
BE IT HEREBY RESOLVED, that the Commission of Public Utility District No. 1 of Benton County declare the equipment listed below surplus because it is unserviceable, obsolete, worn out, unfit, inadequate and/or no longer necessary, material to, and useful in the District's operations, and
BE IT FURTHER RESOLVED, that the General Manager is authorized to dispose of this equipment per District policies.
(TRANSFORMERS, CURRENT TRANSFORMERS, RECLOSER CORE, CAPACITORS, REGULATORS, SWITCH CABINETS, BREAKER, SECTIONALIZER – AS SHOWN ON ATTACHED LIST)
_________________________________ Jeffrey D. Hall, President
Attest: _________________________________ Barry A. Bush, Secretary
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Transformers for Surplus/Disposal
Item D/N Type Ph Secondary ID Pri High Pri Low Sec High Sec Low Kva PPM
1 11628 UG 3 S780199N 12470 7200 208 120 300 LT1
2 13327 UG 1 801127185 12470 7200 240 120 25 LT1
3 13473 OH 1 81VC068132 7200 12470 120 240 25 LT1
4 13980 UG 1 83M96779 12470 7200 240 120 25 LT1
5 14871 OH 1 P430307YRC 7200 12470 120 240 10 LT1
6 15652 OH 1 90NN084013 7200 12470 120 240 10 LT1
7 15946 OH 1 35U2850547 7200 12470 120 240 15 LT1
8 16005 OH 1 2209684091 7200 12470 120 240 10 LT1
9 16494 UG 1 40V3225030 12470 7200 240 120 25 LT1
10 18904 OH 1 1466960799 7200 12470 120 240 15 LT1
11 18919 OH 1 1466880799 7200 12470 120 240 15 LT1
12 19085 UG 1 1525050899 12470 7200 240 120 50 LT1
13 19418 UG 1 2429081700 12470 7200 240 120 25 LT1
14 20206 UG 1 1790421302 12470 7200 240 120 37.5 LT1
15 20475 UG 1 1723281303 12470 7200 240 120 25 LT1
16 21054 UG 1 405053149 12470 7200 240 120 37.5 LT1
17 21069 UG 1 405053164 12470 7200 240 120 37.5 LT1
18 21865 UG 1 6215795106 12470 7200 240 120 25 LT1
19 21909 UG 1 6022004906 12470 7200 240 120 37.5 LT1
20 22329 UG 1 1547720908 12470 7200 240 120 25 LT1
21 22382 UG 1 3776404108 12470 7200 240 120 25 LT1
22 22799 UG 1 314654510 12470 7200 240 120 25 LT1
23 23015 UG 1 1410441111 12470 7200 240 120 25 LT1
24 24032 UG 1 21409793712 12470 7200 240 120 37.5 LT1
25 24226 UG 1 1813561814 12470 7200 240 120 25 LT1
26 25588 OH 1 1116930318 7200 12470 120 240 10 LT1
27 26947 UG 1 1170080420 12470 7200 240 120 25 LT1
28 2766 OH 1 95620 7200 12470 120 240 50 LT1
29 5581 OH 1 FV312516 7200 12470 120 240 25 LT1
30 5909 OH 1 PED2762 7200 12470 240 480 50 LT1
31 6313 OH 1 682002159 7200 12470 120 240 37.5 LT1
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X Business Agenda
Second Reading
Consent Agenda
Info Only/Possible Action
Info Only
COMMISSION MEETING AGENDA ITEM
Subject: Motion Extending Temporary Changes to the District’s Customer Service Rates and Policies
Agenda Item No:
Meeting Date: July 14, 2020
Presented by: Jon Meyer Staff Presenting Item
Approved by (dept): Jon Meyer Director/Manager
Approved for Commission review:
Rick Dunn
General Manager/Asst GM
Motion for Commission Consideration: Motion extending the following temporary changes that became effective March 16, 2020 to the District’s Customer Service Rates and Policies, Resolution No. 2516:
1) Discontinuance of the assessment of the 1% late fee on past due balances. 2) Suspension of the mailing of Urgent Notices to customers with delinquent account
balances. 3) Suspension of disconnects for non-pay.
These temporary changes do not pertain to the following:
1) Schedule 34 Large Industrial 2) Schedule 51 Street Lighting 3) Schedules 72 through 76, Large Irrigation 4) Schedule 85 Flats – Unmetered Electric Service 5) Customers that meet the definition of an Electricity Intensive Load (EIL)
And authorizing the temporary changes to continue in place through the end of the day on August 1, 2020. Recommendation/Background On March 24, 2020 the Commission ratified changes to the Customer Service Rates and Policies that were made in response to efforts established by the State of Washington to prevent the spread of COVID 19. The Commission recognized these efforts had caused significant disruption to the local economy and created financial hardships for customers who had already lost their jobs or had their work hours reduced. The changes to the Customer Service Rates and Policies were intended to give customers some certainty and relief and included discontinuance of the assessment of late fees, suspending disconnects for non-pay, and suspending Urgent Notices.
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The initial Commission action on March 24, 2020 was to allow the temporary changes to continue until the close of business April 30, 2020. At the same time the Commission was taking action, the Governor was issuing proclamations that ultimately required suspension of disconnects for non-payment and late fees specifically for residential customers. The Commission took additional action over the next several Commission meetings to extend these changes for all rate classes. The latest extension occurred at the June 9, 2020 Commission meeting which suspended disconnects for non-pay, late fees, and urgent notices through July 28, 2020 for residential and general service customers. It excluded customer classes that were more industry specific and where such industries had not been required to close or reduce business as a result of the Governor’s Stay Home Stay Healthy orders. At the time, this suspension was in alignment with the latest Governor’s Proclamation (20-23.5) requiring the suspension for residential customers through July 28, 2020, and went a step further by continuing the suspension to general service rate classes. The Governor issued Proclamation 20-23.6 on July 2, 2020, that extends the suspension of disconnect for non-pay and late fees for residential customers through August 1, 2020. The motion included in this agenda item aligns the District’s suspension through the same date and maintains the suspension for general service customers. Staff will continue to monitor any future proclamations made by the Governor and discuss such items with the Commission at future Commission meetings. Proclamation 20-23.5 also required utilities to implement a COVID-19 Customer Support Program by July 10 consistent with guidance published by the Governor’s office. This guidance was pulled by the Governor’s office after consultation with stakeholder groups, including WPUDA shortly after it was issued. After input from the various stakeholder groups, new guidance for a COVID-19 Customer Support Program was included with Proclamation 20-23.6. Proclamation 20-23.6 requires utilities to have a COVID-19 Customer Support Program consistent with the Guidance document to have been reviewed and prominently included on the utility’s website by August 1, 2020. Both Proclamation 20-23.6 and the Guidance document are included in this agenda item for reference. The District has already taken action on establishing a long-term payment arrangement plan at the June 23, 2020 Commission meeting creating a 12-month long-term payment arrangement program and changes to Pay as You Go, once the suspension of disconnects expires. Staff will continue reviewing the Guidance document and bring any future recommendations back to the Commission. Staff believes current established District actions and processes meet many of the suggested items in the document. Staff will continue to work with customers who are past due to obtain payments based on the customer’s ability to pay, and to make payment arrangements. Summary Temporarily waiving late fees, suspending Urgent Notices and suspending disconnects will give customers who are already highly anxious and economically impacted by the COVID 19 situation some assurance that they are not at risk of being disconnected for non-payment, and that they are not being penalized if their account becomes past due.
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Fiscal Impact Suspending Urgent Notices and Disconnects may result in a delay in the collection of accounts receivable and potentially, could result in an increase in write-offs. The suspension of late fees will cause the District to forego revenue. Average monthly late fees assessed during the months of March through July is approximately $11,000.
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PROCLAMATION BY THE GOVERNOR
AMENDING AND EXTENDING EMERGENCY
PROCLAMATIONS 20-05 and 20-23, et seq.,
20-23.6
Ratepayer Assistance and Preservation of Essential Services
WHEREAS, on February 29, 2020, I issued Proclamation 20-05, proclaiming a State of
Emergency for all counties throughout Washington State of as a result of the coronavirus disease
2019 (COVID-19) outbreak in the United States and confirmed person-to-person spread of
COVID-19 in Washington State; and
WHEREAS, as a result of the continued worldwide spread of COVID-19, its significant
progression in Washington State, and the high risk it poses to our most vulnerable populations, I
have subsequently issued amendatory Proclamations 20-06 through 20-53 and 20-55 through
20-61 exercising my emergency powers under RCW 43.06.220 by prohibiting certain activities
and waiving and suspending specified laws and regulations; and
WHEREAS, the COVID-19 disease, caused by a virus that spreads easily from person to person
which may result in serious illness or death and has been classified by the World Health
Organization as a worldwide pandemic, has broadly spread throughout Washington State,
significantly increasing the threat of serious associated health risks statewide; and
WHEREAS, the COVID-19 pandemic has caused a global economic slowdown and an
economic downturn in Washington State, resulting in layoffs and reduced work hours for a
significant percentage of our workforce and significant reductions in business activity impacting
our commercial sectors that support our state’s economic vitality, including severe impacts to the
large number of small businesses that make Washington State’s economy thrive; and
WHEREAS, the available financial resources of many of our people and businesses are
becoming limited with many of them suffering considerable economic hardship as a result of the
economic impacts of the COVID-19 pandemic on our economy, resulting in a significant threat
of utility services being disconnected and late payment fees being imposed; and
WHEREAS, maintaining provision of utility services during this crisis is an essential tool in
sustaining and protecting the health and welfare of our people and businesses as a critical part of
the overall response to the COVID-19 pandemic; and
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WHEREAS, the Washington State Utilities and Transportation Commission regulates the rates
and services of investor-owned utilities in Washington State and is coordinating with utilities
throughout the State to protect the availability and affordability of essential utility services for
those economically impacted by the COVID-19 pandemic through a variety of measures,
including: suspending disconnection of utilities for nonpayment, waiving late fees, working with
affected utility customers to establish payment arrangements, and improving access to energy
assistance for affected customers; and
WHEREAS, on March 18, 2020, I issued Proclamation 20-23, waiving and suspending statutes
and prohibiting certain activities relating to utility services; and
WHEREAS, on March 24, 2020, I issued Proclamation 20-23.1, amending and continuing the
waivers and suspension of statutes and the prohibitions of certain activities relating to utility
services; and
WHEREAS, on April 15, 2020, under the provisions of RCW 43.06.220(4), the statutory
waivers and suspensions in Proclamations 20-23 et seq., were extended by the leadership of the
Washington State Senate and House of Representatives until the termination of the COVID-19
State of Emergency or May 4, 2020, whichever occurs first, and which I acknowledged and
similarly extended the prohibitions therein to until the termination of the COVID-19 State of
Emergency or May 4, 2020, in Proclamation 20-23.2; and
WHEREAS, on May 4, 2020, under the provisions of RCW 43.06.220(4), the statutory waivers
and suspensions of Proclamation 20-23 et seq., were again extended by the leadership of the
Washington State Senate and House of Representatives until the termination of the COVID-19
State of Emergency or May 31, 2020, whichever occurs first, and which I acknowledged and
similarly extended the prohibitions therein to until the termination of the COVID-19 State of
Emergency or May 31, 2020, in Proclamation 20-23.3; and
WHEREAS, on May 29, 2020, under the provisions of RCW 43.06.220(4), the statutory waivers
and suspensions of Proclamation 20-23 et seq., were again extended by the leadership of the
Washington State Senate and House of Representatives until the termination of the COVID-19
State of Emergency or June 17, 2020, whichever occurs first, and which I acknowledged and
similarly extended the prohibitions therein to until the termination of the COVID-19 State of
Emergency or June 17, 2020, in Proclamation 20-23.4; and
WHEREAS, on June 17, 2020, under the provisions of RCW 43.06.220(4), the statutory waivers
and suspensions of Proclamation 20-23 et seq., were again extended by the leadership of the
Washington State Senate and House of Representatives until the termination of the COVID-19
State of Emergency or July 1, 2020, whichever occurs first, and which I acknowledged and
similarly extended the prohibitions therein to until the termination of the COVID-19 State of
Emergency or July 1, 2020, in Proclamation 20-23.5; and
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WHEREAS, on July 1, 2020, under the provisions of RCW 43.06.220(4), the statutory waivers
and suspensions of Proclamation 20-23 et seq., were again extended by the leadership of the
Washington State Senate and House of Representatives until the termination of the COVID-19
State of Emergency or August 1, 2020, whichever occurs first; and
WHEREAS, to fully extend Proclamations 20-23, et seq., it is also necessary for me to extend
the prohibitions therein; and
WHEREAS, the worldwide COVID-19 pandemic and its progression throughout Washington
State continues to threaten the life and health of our people as well as the economy of
Washington State, and remains a public disaster affecting life, health, property or the public
peace; and
WHEREAS, the Washington State Department of Health continues to maintain a Public Health
Incident Management Team in coordination with the State Emergency Operations Center and
other supporting state agencies to manage the public health aspects of the incident; and
WHEREAS, the Washington State Military Department Emergency Management Division,
through the State Emergency Operations Center, continues coordinating resources across state
government to support the Washington State Department of Health and local health officials in
alleviating the impacts to people, property, and infrastructure, and continues coordinating with
the Department of Health in assessing the impacts and long-term effects of the incident on
Washington State and its people.
NOW, THEREFORE, I, Jay Inslee, Governor of the state of Washington, as a result of the
above-noted situation, and under Chapters 38.08, 38.52 and 43.06 RCW, do hereby proclaim that
a State of Emergency continues to exist in all counties of Washington State, that Proclamation
20-05 and all amendments thereto remain in effect, and that Proclamations 20-05, 20-23, et seq.,
are amended to (1) recognize the extension of statutory waivers and suspensions therein by the
leadership of the Washington State Senate and House of Representatives until the termination of
the COVID-19 State of Emergency or 11:59 p.m. on August 1, 2020, whichever occurs first, and
(2) similarly extend the prohibitions therein until termination of the COVID-19 State of
Emergency or 11:59 p.m. on August 1, 2020.
I again direct that the plans and procedures of the Washington State Comprehensive Emergency
Management Plan be implemented throughout state government. State agencies and departments
are directed to continue utilizing state resources and doing everything reasonably possible to
support implementation of the Washington State Comprehensive Emergency Management Plan
and to assist affected political subdivisions in an effort to respond to and recover from the
COVID-19 pandemic.
I continue to order into active state service the organized militia of Washington State to include
the National Guard and the State Guard, or such part thereof as may be necessary in the opinion
of The Adjutant General to address the circumstances described above, to perform such duties as
directed by competent authority of the Washington State Military Department in addressing the
outbreak. Additionally, I continue to direct the Washington State Department of Health, the
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Washington State Military Department Emergency Management Division, and other agencies to
identify and provide appropriate personnel for conducting necessary and ongoing incident related
assessments.
FURTHERMORE, as a condition of the prohibitions under this proclamation, as amended, I
require all utilities providing energy, telecommunications, and water services in Washington
State to develop COVID-19 Customer Support Programs, consistent with the attached guidance
document. The programs must be reviewed and posted prominently on a public website by
August 1, 2020.
ADDITIONALLY, the prohibitions on disconnecting, refusing to reconnect, and charging late
fees in this proclamation, as amended, are extended until termination of the COVID-19 State of
Emergency or 11:59 p.m. on August 1, 2020.
Violators of this order may be subject to criminal penalties pursuant to RCW 43.06.220(5).
Signed and sealed with the official seal of the state of Washington on this 2nd day of July, A.D.,
Two Thousand and Twenty at Olympia, Washington.
By:
/s/
Jay Inslee, Governor
BY THE GOVERNOR:
/s/
Secretary of State
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COVID-19 Utility Customer Support
Program Guidance All utilities have a general obligation to provide safe, reliable, and affordable essential services to their customers. On April 20th, Governor Inslee announced Washington’s Recovery Plan, which includes ensuring access to essential services during the state’s recovery from the COVID-19 pandemic. On May 1, Governor Inslee announced the “Safe Start” approach for Washington state to begin reopening some businesses safely and continue essential businesses. On July 2nd, Governor Inslee issued Proclamation 20-23.6, extending, and amending Proclamation 20-23, pertaining to Utility Ratepayer Assistance and Preservation of Essential Services through August 1st, 2020. Proclamation 20-23.6 extended prohibitions on utilities disconnecting service, refusing to reconnect service, and charging late fees.
This document provides a framework for ensuring that customers experiencing economic hardship as a direct result of the COVID-19 pandemic maintain access to essential services after Proclamation 20-23.6 expires; by adopting consumer protections, customer support programs, and notification protocols, and participating in public information requests. This guidance applies to residential energy, water, and landline telephone services.
This guidance does not relieve customers from the obligation to pay for utility services.
General Guidance for all Utilities
Beginning immediately, utilities covered by the guidance should review existing policies concerning disconnection of service, reconnection of service, payment arrangements, and suspension of other fees or charges, and update those policies as appropriate and necessary to assist vulnerable individuals and households to maintain essential services during the economic recovery.
The public should have access to reliable and accurate information about assistance that may be available from their utilities and their local community to help them recover from the economic impacts of COVID-19. Utilities are trusted sources of information and assistance; their communications with customers are essential to this effort. Customers who are having trouble paying their bill should first contact their utility. Utilities should proactively reach out to customers with accounts in arears to encourage customers to enter into payment arrangements.
COVID-19 Consumer Protections:
Many utilities have existing consumer protection policies in place, and have adopted additional protections to keep customers connected to essential services during the COVID-19 pandemic. In order to assist vulnerable individuals and households with maintaining access to essential services during the economic recovery, energy utilities should consider, at a minimum, the following consumer protections:
1. Prohibit disconnections for low-income and vulnerable households through a date certain;
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2. Waive fees associated with late payments, disconnection, and reconnection of service; and
3. Establish protections for customers under any pre-paid meter plans to ensure continued provision of essential services.
COVID-19 Customer Support Program Principles:
Each utility providing residential energy, water, or telecommunications services will offer COVID-19 Customer Support programs. These programs may include existing services provided to customers experiencing economic hardship and/or additional programs created for the purpose of supporting those directly affected by COVID-19.
The COVID-19 customer support programs should follow these principles:
1. All programs must be reviewed subject to a public process, or approval by the governing body of the utility, consistent with the utility’s standard practice, and prominently posted on a public website, if available. Utilities should also notify customers of their COVID-19 Customer Support Programs in a bill insert, mailing, or other appropriate method of communication.
2. Utility programs should encourage customers with arrearages to contact the utility to help coordinate assistance programs and make efforts to contact these customers directly by phone, email, door tags or premise visits, if necessary. Contact information should be provided on all customer bills and notifications.
3. Utility programs should be designed to ensure that customers maintain access to essential services during the economic recovery from the COVID-19 pandemic.
4. Utilities should take active steps to review current customer assistance programs, and modify them, as appropriate, to address the needs of all customers.
5. Utilities should offer long-term payment arrangements for those directly affected by COVID-19 to allow customers to recover successfully from the unexpected economic impacts of the pandemic. Six to eighteen months, or longer may be appropriate, considering each customer’s unique circumstances.
6. Utilities should work with state and local agencies to help identify customers experiencing economic hardship as a direct result of the COVID-19 pandemic, and help those customers gain access to bill assistance.
Additional customer support efforts and outreach are encouraged and are not limited based on these set of recommendations. The UTC, for utilities under its jurisdiction, and local governing boards of consumer owned utilities are encouraged to adopt policies and procedures focused on the unique needs of their consumers.
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Guidance for Energy Utilities
The following guidance applies to energy utilities providing electric or natural gas service, including municipal utilities and public utility districts authorized under Title 35 RCW and Title 54 RCW; cooperatives formed under Chapter 23.86 RCW; and electrical and natural gas, companies regulated by the Utilities and Transportation Commission under Title 80 RCW.
Energy Utility COVID-19 Customer Notification and Public Information Guidance:
The following guidance is meant to ensure that the information provided to utility customers and the public is timely and accurate:
1. Utilities should develop outreach and communications plans to provide information to customers about options for bill payment assistance and payment plans. This may include communications via website, bill inserts, and direct telephone and email communications initiated by the utility and/or customer. Where needed, information should be provided in languages other than English.
2. The Utilities and Transportation Commission will serve as the single point of contact within state government for customers seeking energy bill assistance information: Utilities and Transportation Commission Consumer Hotline: 1-888-333-WUTC (9882) or [email protected]. The Utilities and Transportation Commission will develop and implement a communications plan, and provide materials to all utilities for use in their own communications materials.
3. All COVID-19 Energy Utility Customer Support Programs should be posted on the Department of Commerce’s Electric and Natural Gas Rate Payer Assistance Resource. If a utility does not have a website, a copy of the customer support programs or the information to direct customers shall be provided.
Energy Utility Information Requests:
Each energy utility should respond to the Department of Commerce’s Utility Economic Impact and Infrastructure Needs Survey, and any subsequent updates. Subsequent updates may include information on customer assistance programs, as requested by the Department of Commerce.
Each utility should provide requested information to the Department of Commerce for consumer-owned utilities, and the Utilities and Transportation Commission for electric and natural gas companies to help the state assess the impacts of the COVID-19 pandemic on utilities and their customers. This information can be provided in response to the Department of Commerce’s Electric and Natural Gas Sector Economic Impact Survey, or regular reporting updates, as determined by the Department and the Commission. Information requests may include:
• Retail load, by customer class
• Number of arrearages, by customer class, over each specified time-period: 30 day, 60 day, 90+ day arrears
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• Total amount of past due receivable, by customer class, over each specified time-period: 30 day, 60 day, 90+ day arrears
• Number of customers eligible for disconnection
• Number of disconnections, by customer class
• Number of reconnections after disconnection, by customer class
• Average duration of disconnection, by customer class
• Number and duration of completed deferred payment plans,
• Number of premises enrolled in a bill assistance program
• Number of customers in the 30, 60, and 90 day who have received bill payment assistance in the last 12 months, and last 24 months
• Expenditures for the following programs:
o COVID related-emergency assistance funds
o Low-income bill assistance
o Low-income or other rate discount programs
Guidance for Water Utilities
The following guidance applies to community water systems, including municipal utilities, public utility districts, and water and sewer districts authorized under Title 35 RCW, Title 54 RCW, and Title 57 RCW; water companies regulated by the Utilities and Transportation Commission under Title 80 RCW; and mutual corporations or associations formed under Chapter 24.06 RCW.
Water Utility COVID-19 Customer Support Programs:
Community water systems have a multitude of customer assistance programs already established, many smaller systems may have more informal programs that help their neighbors. And others may still need to create or update their program. Currently the most readily available option for water utilities is to offer payment plans that allow the utility and the customer to reach an agreement on a reduced payment amount.
Because of the severity of the COVID-19 pandemic and economic crisis, community water systems with more than 1,000 customers should establish at a minimum Customer Assistance programs that ensure customers impacted by experiencing hardship due to the COVID-19 pandemic maintain access to essential services after Proclamation 20-23 expires. Options to consider for a customer assistance plan include, but are not limited to:
1. Bill arrearage forgiveness; or
2. Payment plan where shut offs do not occur if the customer consistently pays an agreed to amount of their arrearages accrued monthly; or
3. Provide a combination of the above.
75
Water Utility COVID-19 Customer Notification Guidance:
The public should have access to reliable and accurate information about assistance that may be available from their utilities and their local community to help them recover from the economic impacts of COVID-19. Utilities are trusted sources of information and assistance; their communications with customers are essential to this effort.
1. Water systems should inform customers about their customer assistance programs and how to receive assistance. Customers with accounts in arrears should be contacted directly. All customers should be notified of available assistance programs by one of the following methods:
• Notify all customers that a customer assistance program is available and provide a direct URL for the customer assistance program web page (if one exists) either by mail or email.
• Direct email providing a copy of customer assistance options.
• Electronic or hard copy customer bills and notifications.
• Hard copy special announcement delivered through the U.S. Mail.
4. The Department of Health will serve as the single point of contact within state government for information sharing, guidance, and technical assistance for community water systems and their customers. The Department will:
a. review sample policies, and customer assistance programs, and develop templates, and best practices;
b. Create and post guidance and frequently asked questions documents for water utility customers; and
c. Continue to provide email updates to community water systems during the COVID crisis.
To contact the Department of Health for technical assistance or concerns on customer assistance programs:
Phone: (360) 236-3100
Water Utility Information Requests:
Each community water system should respond to the Department of Health’s Utility Economic Impact and Infrastructure Needs Survey, and any subsequent updates. Subsequent updates may include information on customer assistance programs, as requested by the Department of Health.
Guidance for Telecommunications Companies
The following guidance applies to telecommunications companies and services regulated by the Utilities and Transportation Commission under Title 80 RCW.
76
Telecommunications Company COVID-19 Customer Notification and Public Information Guidance:
The public should have access to reliable and accurate information about assistance that may be available from their utilities and their local community to help them recover from the economic impacts of COVID-19. Utilities are trusted sources of information and assistance; their communications with customers are essential to this effort. For all telecommunications companies with more than 1,000 customers:
1. Telecommunications companies should develop outreach and communications plans to provide information to customers about options for bill payment assistance and payment plans. This may include communications via website, bill inserts, and direct telephone and email communications initiated by the utility and/or customer. Where needed, information should be provided in languages other than English.
2. The Utilities and Transportation Commission will serve as the single point of contact within state government for customers seeking energy bill assistance information: Utilities and Transportation Commission Consumer Hotline: 1-888-333-WUTC (9882) or [email protected].
3. All COVID-19 Utility Customer Support Programs should be posted on a publically accessible website.
Telecommunications Company Information Requests:
The Utilities and Transportation Commission has authority to request information from telecommunications companies pertinent to implementation of this guidance.
Questions?
General questions about how to comply with the guidance can be submitted to the state’s Business Response Center at: https://coronavirus.wa.gov/how-you-can-help/covid-19-business-and-worker-inquiries
All other violations related to Proclamation 20-25 can be submitted at https://bit.ly/covid-compliance
77
X Business Agenda
Second Reading
Consent Agenda
Info Only/Possible Action
X Info Only
COMMISSION MEETING AGENDA ITEM
Subject: Broadband Business Update
Agenda Item No:
Meeting Date: July 14, 2020
Presented by: Rich Nall (NoaNet) Staff Presenting Item
Approved by (dept): Chris Folta Director/Manager
Approved for Commission review:
Rick Dunn General Manager/Asst GM
Motion for Commission Consideration: None. Recommendation/Background Recommend that a presentation be shared with the Commission to review the Broadband Business year-to-date financial and Line Extension Credit performance along with a status on the recently approved advanced wireless/small cell project. Summary None. Fiscal Impact None.
7b
78
BROADBAND BUSINESS UPDATE
COMMISSION PRESENTATION
JULY 14, 2020
79
AGENDA
❖ Broadband Business Performance 2020
❖Resolution 2432
❖Current State 2020
❖Quotes and Service Orders
❖Financials
❖Proforma
❖Line Extension Credit (LEC) Performance
❖ USC CRAN – Small Cell Project
❖NoaNet Update
80
RESOLUTION 2432: BROADBAND STRATEGY
• Continue to account for broadband financial activities
within the Electric System Fund; comply with Washington
State Auditor
• Wholesale rates to retail service providers will be based on
competitive pricing principles; financial planning to
maintain net positive cash flows over rolling five-year
period, both looking back and forward
• NoaNet will continue to provide management of
broadband business through Network Coordinated Services
• District will remain an active owner/member of NoaNet
and to provide periodic updates to the Commission
81
CURRENT STATE 2020
• COVID 19
– Impact has been minimal so far for existing customers
– Best 1st and 2nd quarters to date
• Partnerships & Strategic Agreements
– Working with Ziply on teaming agreement for FTTH
– New MSA internet customers
– CoLo opportunity for DOE
– Small Cell opportunities with other carriers
• New Rates
– Still evaluating small business Access Internet rates and LEC
– Increase in bandwidth for Access Internet customers
82
QUOTES AND SERVICE ORDERS COMPARISON
• 2018 Quotes: 257
• 2018 SO Access Internet: 68
• 2018 SO Other: 19
• 2019 Quotes Total: 191
• 2019 SO Access Internet: 72
• 2019 SO Other: 22
• 2020* Quotes Total: 106
• 2020* SO Access Internet: 44
• 2020* SO Other: 17
*Year through July 6, 2020th
94
87
61
83
BROADBAND BUSINESS PROFORMA
BENTON PUD PRO FORMA
LINE ITEM DESCRIPTION YTD (May) 2020 2021 2022 2023
Revenues
Transport, Wireless, Dark Fiber Revenues $1,005,111 $2,338,253 $2,373,327 $2,610,993 $2,650,158
Access Internet Revenue $134,731 $300,000 $349,000 $409,000 $419,000
USC CRAN $199,080
Total Revenues$1,139,842 $2,638,253 $2,921,407 $3,019,993 $3,069,158
Operating Expenses
NoaNet NCS$(702,831) $(778,263) $(804,526) $(817,624)
Fiber Leases, Maintenance, District Labor$(368,462) $(375,832) $(383,348) $(391,015)
O&M Direct Costs$(460,692) $(1,071,293) $(1,154,094) $(1,187,874) $(1,208,639)
Capital Expenditures
Aid to Construction$59,769 $73,500
Capital (LEC's, Laterals, Electronics)$(370,041) $(1,562,500) $(1,092,649) $(1,072,468) $(1,050,468)
USC CRAN$(410,000) $(410,000)
Total Capital$(310,272) $(1,899,000) $(1,502,649) $(1,072,468) $(1,050,468)
Total O&M and Capital$(770,964) $(2,970,293) $(2,656,743) $(2,260,342) $(2,259,107)
Net Cash To/From Broadband$368,878 $(258,540) $264,663 $759,651 $810,051
84
LINE EXTENSION CREDIT PERFORMANCE: 2020
LEC 1 2020 YTD
Fiber Customers Average Fiber Build Costs Net Capital Average Fiber Revenue Monthly Revenue
27 $4,625 $124,865 $305 $8,230
LEC 2 2020 YTD
Fiber Customers Average Fiber Build Costs Net Capital Average Fiber Revenue Monthly Revenue
21 $5,802 $121,848 $104 $2,190
On-Net 2020 YTD
Fiber Customers Average Fiber Build Costs Capital Average Fiber Revenue Monthly Revenue
13 $0 $0 $117 $1,515
Combined New Builds & On-Net 2020 YTD
Fiber Customers Average Fiber Build Costs Net Capital Average Fiber Revenue Monthly Revenue
61 $4,044 $246,713 $196 $11,935
2020 YTD LEC Totals
LEC 1 LEC 2 Lateral AtoC Net Construction Capital
$210,196 $159,948 $16,009 $123,431 $262,722
85
USC CRAN UPDATE
• Permitting
– Small Cell Franchises submitted
– Joint Use Agreements under review
– Site drawings for CRANs in process
• Hub Entrance Fiber
– Construction of entrance fiber for all 7 Hub locations in
progress
• Capital
– Projecting only 50% of capital for 2020 to be spent ~$410K
– All new revenues to be recognized in 2021
86
NOANET UPDATE
• Core Network Upgrade
– Member Loan provided capital financing
• Banking Relationship
• Pension Funding
• State Wi-Fi Support & Leadership
87
Questions?
88
Business Agenda
Second Reading
Consent Agenda
Info Only/Possible Action
X Info Only
COMMISSION MEETING AGENDA ITEM
Subject: Benton PUD 2020 Integrated Resource Plan Update
Agenda Item No:
Meeting Date: July 14, 2020
Presented by: Kevin White /s/ Kevin White Staff Presenting Item
Approved by (dept): Kevin White /s/ Kevin White Director/Manager
Approved for Commission review:
Rick Dunn General Manager/Asst GM
Motion for Commission Consideration
None Background
Chapter 19.280 RCW requires utilities to develop an Integrated Resource Plan (IRP) every four years beginning September 1, 2008. Progress reports reflecting changing conditions must be submitted at a minimum interval of two years. The Clean Energy Transformation Act (CETA) legislation passed in 2019 includes additional IRP requirements. Staff from the District and The Energy Authority (TEA) are working to develop the updated IRP for the 2021 - 2030 time period. A copy of the IRP must be submitted to the Department of Commerce by September 1, 2020. Summary
Staff will provide an update on the 2020 IRP. A resolution to adopt the final 2020 IRP will be brought to Commission in August 2020. Fiscal Impact
The 2020 IRP cost estimate of $73,000 is included in the $175,000 2020 budget for Activity 2 TEA Consulting Task Order.
7c
89
2020 Integrated Resource Plan Update1
Commission Presentation – July 14, 2020
Your Trusted Energy Partner90
2020 Integrated Resource Plan Update – July 14, 2020
2020 IRP Schedule2
Janu
ary
Febru
ary
Marc
h
Ap
ril
May
June
July
Aug
ust
Septe
mber
TEA Analysis: Capacity Expansion Model, Aurora Pricing Model, Stochastic Cost Model, and Resource Portfolio Analysis
Commission UpdateJune 9
Commission Updates
July 14 & 28
Public Hearing & Commission
AdoptionAugust 11
IRP Filing Due September 1
Draft IRP prepared and reviewed by TEA /
District Staff
Final IRP prepared and reviewed with
Commission
91
2020 Integrated Resource Plan Update – July 14, 2020
Sun 7 65 44 -2 -16 -34 35 48 -2 107 76 53 116 91 47 64 34 65 65 55 32 -4 -49 16 -32 27 -47 -108 -38 -48 -92 -88 -38 -42 21 -39 -18 -32 -23 16 7 25 -26 8 57 -30 47 -39 31 20 83 68
Mon -18 72 4 -13 -25 -49 39 -23 -19 94 63 28 57 43 3 13 40 45 3 9 6 -58 -60 23 -85 -43 -98 -133 -71 -131 -157 -123 -98 -68 -36 -88 -41 -44 -10 -50 -28 -21 -6 38 44 -76 24 -43 34 27 101 37
Tue -4 51 7 -6 -61 -12 48 -8 48 53 32 33 58 43 16 26 9 43 -16 -25 -14 -35 -50 40 -74 -84 -124 -134 -63 -126 -126 -123 -89 -74 -73 -94 -39 -35 -19 -60 -18 -3 15 65 -34 -68 51 -49 45 27 99 -11
Wed -19 25 21 -1 2 -99 15 47 -22 80 32 26 43 78 47 26 34 -14 38 -42 -36 -14 -49 -68 -15 -43 -59 -125 -139 -66 -122 -103 -69 -59 -96 -21 -40 -22 -17 -20 -40 -15 11 24 34 -25 -57 42 -21 52 40 98 -27
Thu -2 35 13 -22 6 -123 44 19 -12 76 45 38 39 63 28 56 65 -13 39 -59 -62 -8 -46 -32 -45 1 5 -102 -120 -29 -110 -106 -13 -30 -64 -34 -45 -55 -13 -22 -52 30 16 22 43 -40 -19 87 2 67 31 86
Fri 47 63 9 11 8 -95 37 30 6 94 98 13 42 59 36 47 58 -14 69 -27 -9 -24 -38 15 -17 7 -6 -106 -96 -54 -141 -75 -1 -59 -43 -95 -56 -65 -43 -8 -47 1 27 -1 39 -18 -15 97 5 66 69 42
Sat 21 61 -8 11 -36 -53 49 55 -28 85 87 7 106 59 55 18 60 34 80 25 16 -46 -38 0 -17 45 -48 -110 -73 -38 -68 -69 -14 -19 28 -20 -45 -54 0 -5 -28 5 -6 47 50 -47 24 -2 60 46 71 76
Sun 31 91 118 67 72 119 108 91 68 72 61 95 110 29 36 -29 -31 -5 -61 47 -35 -91 -155 -139 -112 -191 -117 -84 -126 -25 -103 -36 -23 9 43 20 -55 -30 29 17 -6 11 15 53 47 17 -22 -37 42 66 0 2
Mon 117 58 100 72 52 104 85 29 46 34 75 60 44 42 -29 -37 -29 -49 -53 -22 -43 -58 -174 -127 -136 -176 -121 -94 -112 -42 -94 -73 -53 -38 -17 15 -6 -52 -17 -13 -37 -9 4 25 29 -23 -10 -46 3 41 8 33
Tue 82 54 72 57 60 122 49 41 50 66 72 65 62 37 -12 -32 -57 -48 -24 -45 -56 -46 -172 -144 -146 -166 -157 -95 -98 -74 -98 -105 -71 -48 -41 -43 26 -26 -13 -35 -43 -6 -5 13 9 56 6 -25 78 27 55 30
Wed 45 61 55 59 77 96 53 55 12 69 61 57 78 25 -30 6 -39 13 7 -46 -75 -87 -174 -143 -117 -148 -154 -98 -74 -89 -70 -129 -80 -71 -9 -58 8 -16 -9 4 -13 -25 -18 -5 28 17 14 0 82 40 30 21
Thu 32 48 76 66 81 84 107 78 86 37 41 52 63 77 25 -28 6 -53 -40 85 -71 -123 -83 -154 -127 -174 -156 -173 -88 -65 -105 -71 -123 -48 -77 -38 -60 -10 9 -25 -16 -16 -27 14 14 21 30 -7 -6 74 11 8 -35
Fri 28 73 81 68 65 93 97 79 103 46 51 72 80 33 32 -22 13 -28 -55 42 -41 -127 -112 -121 -117 -177 -143 -127 -134 -70 -109 -98 -21 -19 -7 11 -47 -32 -41 -46 -16 3 -19 3 8 68 -30 -24 38 66 32 11
Sat 28 81 77 68 113 129 113 116 70 93 74 76 107 57 -3 -7 -21 11 -53 36 -35 -101 -142 -97 -129 -170 -128 -54 -108 -9 -127 -77 -37 -28 15 -2 -69 -41 -13 -8 -67 -17 -9 25 52 46 -8 -71 38 75 22 -38
Sun -11 25 42 8 69 22 68 73 88 101 96 108 64 59 25 52 63 37 45 87 46 -24 -115 -31 11 -63 -32 35 -41 -64 -57 -38 -91 -63 -33 -25 -32 -6 12 -27 0 57 50 64 74 78 51 64 51 -9 -52 17
Mon -18 14 48 26 30 3 124 23 63 93 19 82 39 63 32 10 61 -18 34 59 10 -56 -152 -7 -72 -120 -19 -4 -33 -103 -99 -52 -112 -68 -67 -69 -38 -10 -38 -16 37 1 47 -5 66 75 24 55 -3 -4 -46 36
Tue 5 13 40 50 13 2 105 27 54 64 57 55 14 41 47 7 11 -46 15 -23 -41 -93 -149 14 -63 -135 -38 -42 -23 -106 -56 -40 -109 -73 -36 7 -16 -9 -40 4 16 48 15 66 54 64 6 8 -8 -30 53 47
Wed 8 -29 42 80 9 18 52 49 56 85 42 60 -2 40 57 -8 28 -25 -17 -41 -36 -38 -59 -7 -84 -140 -43 -63 -54 -117 -89 -62 -123 -89 -50 -30 -3 13 -38 -6 -2 23 -5 43 50 56 45 45 -9 -53 24 55
Thu 42 22 58 71 36 52 93 36 58 99 57 80 30 33 64 17 20 33 -42 -8 12 -18 -30 0 -36 -123 -33 -72 -96 -126 -100 -83 -125 -80 -53 -44 -4 9 -48 -38 14 41 49 41 65 37 75 56 -36 -29 -4 13
Fri -32 41 46 32 71 34 59 94 51 57 71 22 64 69 17 60 43 55 21 -44 21 -5 -73 1 -6 -13 -49 0 -60 -49 -134 -114 -89 -71 -85 -26 -28 -15 3 5 6 64 35 31 48 79 19 77 33 -2 -37 11 43
Sat -66 27 46 12 37 -2 84 107 100 93 102 68 78 56 25 56 60 38 -5 48 42 -11 -82 0 -5 -28 -39 17 -43 -42 -82 -72 -88 -71 -71 -14 -57 -15 16 8 -8 0 42 36 53 72 56 61 70 1 -82 29 28
Sun 24 -16 -34 30 17 -2 7 61 61 70 108 74 102 113 69 83 91 69 86 86 -12 -48 29 26 -13 -70 -43 -56 -43 -98 -109 -88 -32 -16 -57 -49 10 1 30 -8 47 -9 23 7 -3 42 20 45 38 38 39 -21 -6
Mon -41 1 -52 3 -13 7 -51 56 40 31 78 41 72 61 60 87 76 72 47 48 -64 -69 -29 31 -76 -108 -60 -71 -59 -92 -99 -116 -42 -75 -105 -67 -43 3 -3 13 -3 -21 6 -2 3 7 43 -23 7 14 66 -49
Tue -20 -20 -59 20 13 -34 -45 49 35 45 76 56 66 40 25 85 69 62 32 64 -90 -95 -76 38 -85 -60 -45 -64 -89 -102 -138 -112 -45 -96 -103 -81 -54 -16 12 20 -8 -30 16 -44 -72 36 32 37 -11 19 26 23
Wed -54 -21 -10 9 -75 -31 -23 37 43 39 91 49 65 77 67 65 64 31 12 63 -9 -31 -73 15 -52 -49 -107 -81 -76 -114 -120 -114 -65 -80 -83 -33 -15 32 3 20 17 4 12 15 15 48 26 48 4 11 42 6
Thu -103 -82 29 9 -45 -26 10 -11 54 51 68 55 62 85 63 56 55 -11 56 42 2 19 48 22 -73 -65 -112 -68 -25 -89 -132 -123 -67 -53 -76 -17 -2 41 11 11 9 -9 27 -1 31 32 67 34 12 23 7 27
Fri -90 -102 16 17 -35 31 35 19 63 87 51 81 54 82 64 58 46 93 63 6 -30 -30 45 34 -50 -86 -128 -96 -69 -118 -134 -111 -81 -47 -68 -31 -1 32 16 -6 15 28 19 -18 30 48 60 55 27 34 4 23
Sat -97 -44 30 37 -6 55 68 22 82 93 111 110 106 88 64 94 80 103 93 15 -45 -39 47 19 -40 -53 -86 -70 -87 -80 -98 -91 -36 -52 -84 -12 -14 11 -3 -17 13 -4 -29 -7 45 51 7 16 -20 7 21 -2
Sun 47 67 109 105 126 62 68 78 50 80 69 88 43 68 108 78 66 85 50 3 9 -1 52 2 -65 -16 -40 -79 -69 -111 -115 -46 -20 53 -35 -35 1 25 10 -30 22 -3 24 43 2 4 15 33 -38 6 -8 36
Mon 10 35 61 77 84 58 39 29 29 27 28 56 45 37 68 70 32 39 11 -40 -54 -46 -6 -15 -14 -43 -4 -89 -129 -102 -107 -105 -70 -24 35 -1 -31 -7 16 -8 -30 8 12 -7 47 -38 -25 -6 0 -14 58 -2 -11
Tue 17 56 60 64 95 72 4 -19 22 -1 60 23 46 -8 61 51 26 52 5 -36 -81 -35 -18 -17 -56 -34 -22 -36 -120 -105 -106 -110 -59 -46 -9 -45 -15 2 -11 -25 28 -17 28 -10 64 -8 -26 31 11 0 58 33
Wed 32 52 73 109 68 88 41 -9 65 7 68 46 48 37 44 36 23 30 76 17 -74 -23 -32 -5 -86 -42 -11 -85 -109 -110 -154 -106 -60 -42 -33 -34 -17 -8 -3 -15 8 -5 21 14 37 1 -36 36 0 61 58 15
Thu 19 66 82 77 66 70 36 -17 59 41 45 46 43 63 53 56 25 20 80 1 -59 18 -6 -37 -66 -37 -99 -106 -71 -115 -92 -126 -100 -39 -28 -68 -29 -6 -29 -26 -22 -22 10 56 8 -9 15 12 -26 58 53 -8
Fri 39 60 75 72 88 85 61 -29 52 54 40 37 79 62 67 63 7 30 101 17 -25 54 -11 -73 -48 -54 -73 -112 -61 -83 -79 -103 -47 -7 -12 -60 -3 -9 -28 -31 24 1 41 58 -9 37 40 27 -6 35 49 -19
Sat 29 101 101 126 112 77 104 73 5 55 69 89 58 94 58 56 45 58 89 4 8 7 51 8 -23 -58 -25 -136 -61 -105 -81 -106 -62 13 -57 -68 7 -20 -30 -12 9 -17 21 79 17 23 32 45 -7 60 38 -9
Sun 107 24 25 49 -11 -48 -11 -17 -111 -29 42 35 45 45 62 98 60 37 -15 90 31 -19 -15 -114 17 -79 -4 -17 -44 -33 -88 24 -16 -43 -64 6.9 -18 1.9 21 25 14 -9 3.1 -8 51 42 37 -9 18 -9 66 17
Mon 49 7 54 40 -52 -94 -53 -23 -107 -69 -9 31 81 25 49 73 55 -1 -1 43 23 -57 -87 -125 -53 -67 -39 -56 -88 -94 -135 -41 -83 -51 -53 -4 40 20 17 -47 3.1 25 -50 -19 27 25 35 -17 4.1 -6 13 4.2
Tue 22 23 18 43 14 -32 -25 -105 -61 -107 -12 -14 55 70 45 50 57 54 -13 36 82 -20 -38 -111 -88 -73 9.7 -80 -15 -87 -83 -145 -81 -88 -51 -76 -17 -1 -26 -7 8.7 1.1 12 -22 -32 1 23 -9 -5 -8 -14 12 10
Wed 5 25 32 51 13 -119 0 -47 -40 -34 -3 19 61 44 57 26 57 66 -15 58 62 -17 -44 -131 -49 -54 -28 -76 -20 -44 -73 -136 -72 -40 -68 -53 -26 18 -16 -7 -15 -16 -27 -69 -16 1 33 17 12 0 -27 16
Thu 54 41 32 28 21 -112 -8 -47 -31 -16 -29 19 27 79 83 20 59 52 4.2 104 33 -29 32 -118 -42 5.1 -38 -55 -13 -65 -110 -118 -58 -30 -62 -46 -45 -11 -17 -40 -34 10 -6 -23 -9 15 -20 0.5 13 11 -11 34
Fri 57 59 54 14 6 -40 1 -50 -60 -26 -22 90 61 69 41 27 49 37 -19 65 63 -62 7.6 -90 -24 -18 -72 -79 -29 -78 -87 -58 -34 -25 -57 -64 -71 -5 -0 -2 -34 38 8.9 -24 -19 35 -24 -9 13 36 32 -2
Sat 71 49 36 35 21 -46 -1 -20 -33 -11 -15 51 42 53 79 42 8 22 -34 101 50 -33 -6 -101 -31 -50 -10 -61 -37 -88 -80 -26 -16 -12 -44 -58 -50 15 2.3 53 -2 -11 -13 -26 26 20 -21 -29 38 17 45 38
Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec
2019
2014
2015
2016
2017
2018
Focus on Capacity NeedsLong on Energy, Short on Capacity
3
Significant and frequent summer peak hour
deficits and some winter peak hour deficits
200 MW
Deficit
200 MW
Surplus
0
50
100
150
200
250
300
2021 2022 2023 2024 2025 2026 2027 2028 2029 2030
aM
W
Critical Water
BPA Block BPA Critical Slice
BPA Above Critical Slice Future BPA Contract
Other Renewables Frederickson
Capacity Contracts Market Purchases
Load w/ Tx Losses
0
50
100
150
200
250
300
2021 2022 2023 2024 2025 2026 2027 2028 2029 2030
aM
W
Average Water
Annual Average Energy
Long Under Average Water
92
2020 Integrated Resource Plan Update – July 14, 2020
Modeling Process / Social Cost of Carbon (SCC)4
Capacity Expansion Model Portfolio AnalysisForward Power Price Curve
Development
CETA requirement to include the SCC in the IRP process
Influences the projected resources to be built over the planning horizon
Influences the cost associated with carbon emitting resources
93
Capacity Expansion Model5
94
2020 Integrated Resource Plan Update – July 14, 2020
Market Simulation6
95
2020 Integrated Resource Plan Update – July 14, 2020
Regional Load Forecast
Northwest Power and Conservation Council mid-term assessment load assumptions
utilized in capacity expansion modeling
Forecasted average annual growth rate ≈0.4%
7
96
2020 Integrated Resource Plan Update – July 14, 2020
Social Cost of Carbon (SCC)
Adds ≈$32 per MWh to Natural Gas Resources for
capacity expansion modeling and portfolio analysis
8
97
2020 Integrated Resource Plan Update – July 14, 2020
New Resource / Power Purchase Agreements Costs
Resource Type
Capital Cost
($/KW)
Fixed O&M
($/kW - Year)
Variable
O&M
($/MWh)
Full Load
Heat Rate
(BTU/kWh)
Capacity
Factor Fuel Type
Combustion Turbine - Aeroderivative 1,212$ 16.30$ 4.70$ 9.12 10% Natural Gas
Combined Cycle 1,135$ 14.10$ 2.55$ 6.43 28% Natural Gas
Reciprocating Internal Combustion Engine 1,207$ 35.16$ 5.69$ 8.30 11% Natural Gas
Geothermal 2,734$ 128.54$ 1.16$ N/A 73% Geothermal
Small Modular Reactor - EIA Cost 6,191$ 95.00$ 3.00$ 10.45 90% Uranium
Pumped Storage 2,390$ 24.80$ 0.37$ N/A 37% Various
District Owned Resources
Resource Type PPA Cost
Capacity
Factor Fuel Type
Eastern Montana Wind 27.00$ 37% Wind
Columbia Gorge Wind 35.00$ 32% Wind
Single Axis Tracking Solar Photovoltaic‡ 37.00$ 20% Solar
Solar + Storage 65.00$ Solar
Resources Modeled Per Unit
27%
9
98
2020 Integrated Resource Plan Update – July 14, 2020
Levelized Cost of Energy (LCOE)
CF - 32%
CF - 27%
CF - 27%
CF - 27%
CF - 90%
CF - 37%
CF - 28%
CF - 14%
CF - 83%
CF - 10%
CF - 11%
$- $25 $50 $75 $100 $125 $150 $175 $200 $225 $250 $275
Onshore Wind - Montana
Market Power
BPA Contract
Onshore Wind - Columbia Gorge
Solar
11.6 aMW of Benton Conservation
Solar + Storage
Small Modular Reactor - EIA
Pumped Storage
Combined Cycle 2x1
Battery Storage
Biomass
Combustion Turbine - Aeroderivative
Reciprocating Internal Combustion Engine (RICE)
Subsidized Generator LCOE Tax Credit LCOE Social Cost of Carbon
Incentives reduce the LCOE of certain renewable and non-emitting resources
SCC increases the LCOE for fossil fuel resources; lower capacity
factors due to more renewables built
High capacity factor resource; however, LCOE does not include additional cost of displacing hydro during peak runoff times
CF = Capacity Factor
10
99
2020 Integrated Resource Plan Update – July 14, 2020
Northwest Power Pool Capacity Expansion
Natural Gas resources are added in the NWPP capacity expansion; however, those resources are not
built in WA due to the SCC
11
100
2020 Integrated Resource Plan Update – July 14, 2020
California / Mexico Capacity Expansion
Renewable Portfolio Standards and Energy Storage requirements drive resources in the CA / Mexico capacity expansion; however, some Natural Gas resources are needed
12
101
Stochastic Model13
102
2020 Integrated Resource Plan Update – July 14, 2020
Market Simulation14
103
2020 Integrated Resource Plan Update – July 14, 2020
Natural Gas Price and Slice Generation Forecast
Low natural gas prices are forecasted to continue through the 10-year study period
Significant variability in hydro generation impact the range of power market prices
15
104
2020 Integrated Resource Plan Update – July 14, 2020
Historic Prices
Minimal price volatility between 2011 and 2017; 2014 was the original polar vortex event
More recent volatility due to natural gas constraints and extreme weather
16
105
2020 Integrated Resource Plan Update – July 14, 2020
Mid-C Power Market Price Forecast
On average, forecasted HLH prices remain in the low to mid $30’s
On average, forecasted LLH prices remain in the mid to upper $20’s
17
106
2020 Integrated Resource Plan Update – July 14, 2020
Mid-C HLH/LLH Forecasted Price Spread
Starting to forecast very low to negative price spreads in May due to abundance
of solar, wind, and hydro supply
18
107
2020 Integrated Resource Plan Update – July 14, 2020
Winter/Summer Hourly Mid-C Price Forecast
AugustDecember
Evening ramp as CA / NW solar generation fades
Prices follow the natural winter demand curve
19
108
Next Steps20
109
2020 Integrated Resource Plan Update – July 14, 2020
2020 IRP Schedule21
Janu
ary
Febru
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TEA Analysis: Capacity Expansion Model, Aurora Pricing Model, Stochastic Cost Model, and Resource Portfolio Analysis
Commission UpdateJune 9
Commission Updates
July 14 & 28
Public Hearing & Commission
AdoptionAugust 11
IRP Filing Due September 1
Draft IRP prepared and reviewed by TEA /
District Staff
Final IRP prepared and reviewed with
Commission
Capacity and portfolio analysis Proposed IRP adoption
110
X Business Agenda
Second Reading
Consent Agenda
Info Only/Possible Action
Info Only
COMMISSION MEETING AGENDA ITEM
Subject: Wind Power and Clean Energy Policy Perspectives Report
Agenda Item No:
Meeting Date: July 14, 2020
Presented by: Rick Dunn Staff Presenting Item
Approved by (dept): N/A Director/Manager
Approved for Commission review:
Rick Dunn General Manager/Asst GM
Motion for Commission Consideration:
Motion approving attached report entitled “Wind Power and Clean Energy Policy Perspectives” in substantially the form presented as an authoritative representation of the District’s current position. Recommendation/Background
On November 12, 2019 the District adopted Resolution 2523 in support of actions to ensure electric sector resource adequacy in the Pacific Northwest. This resolution provides a sound argument for why northwest utilities have serious concerns regarding the reliability of the northwest power grid and why Benton PUD questions the wisdom of continued development of wind energy in our region when we are facing potentially serious consequences associated with possible power grid blackouts. Among other things, Resolution 2523 resolved that the Commission and Staff will undertake an effort to heighten the awareness of customers and policy makers as to resource adequacy concerns and environmental and land use impacts associated with high wind and solar project development scenarios. Staff developed the “Wind Power and Clean Energy Policy Perspectives Report” in response to Resolution 2523 and recommends the Commission adopt the report as an authoritative representation of the District’s current position. Summary
Approving the recommended motion will establish a report that can be used by the District in our education and outreach efforts aimed at helping readers understand a complex topic from our perspective and at helping shape energy policies with better outcomes for our customers. Fiscal Impact
N/A
7d
111
Rick Dunn, General Manager
Commissioners: Barry Bush
Jeff Hall Lori Sanders
July 14, 2020
Wind Power and Clean Energy Policy Perspectives
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Executive Summary
Clean energy technology and public-policy development continue to be in the news and at the forefront of much political debate and discussion. While wind power has emerged as a popular choice for helping meet greenhouse gas emission reduction goals, reasonable questions continue to be raised regarding its ability to cost-effectively contribute to the powering of modern civilization and how the lifecycle environmental and ecological impacts compare to other types of technologies.
With Washington State’s passage of the Clean Energy Transformation Act (CETA) in 2019 and the current schedule for expiration of renewable energy federal tax credits, there is a resurgence in proposed wind power development activity in the Pacific Northwest (PNW), including projects proposed for eastern Washington and Benton County specifically.
As developers and many elected officials tout the economic and environmental benefits of wind farms, Benton PUD believes it is important for our customers and the general public to hear utility perspectives. Unlike the narrower focus of some wind power interests, utilities must balance environmental benefits and concerns with costs and power grid reliability; and we will be held accountable if we fail on any of these dimensions.
While Benton PUD acknowledges wind power development in the PNW will likely continue as Washington State utilities respond to the 2025 CETA deadline for eliminating coal-fired energy and in response to nearby state and corporate clean energy mandates and goals, we do not support further development of wind power in the PNW for the following primary reasons:
1) Benton PUD’s current power supply is hydro and nuclear based and is over 93% “non-
emitting” by Washington State standards. While we are ahead of the clean energy curve,
we do experience supply deficits during hot summer months and deeply cold winter
periods. To cover these deficits, we make power market purchases from generation
resources that can be counted on to run on the days and hours needed (dispatchable).
Since wind power relies on natural weather conditions decoupled from electricity demand,
it is not dispatchable generation and therefore will not help us resolve our seasonal energy
deficit problems.
2) The PNW’s hydroelectric generation resources are the foundation of a reliable and clean
energy supply that has historically resulted in Washington State contributing no more than 0.5% to the nation’s annual total greenhouse gas (GHG) emissions from electricity production; even with soon to be retired coal-fired power plants in the mix. Further development of wind power in the PNW will not result in consequential reductions in national or global GHG emissions attributable to Washington State utilities and will do very little to mitigate the increasing risk of northwest power grid blackouts; which could grow to a 26% probability by 2026 if utilities are unable to replace the reliable generating capacity of shuttered coal plants.
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3) The low availability of wind power requires utilities to continue paying for dispatchable generation capacity that may run infrequently but is still sized to meet most of the peak energy demand on the grid. This “double paying” is why electricity rates in countries and states with high wind penetrations are rising despite the declining costs of this popular renewable energy source. Benton PUD believes further wind power development will unnecessarily contribute to increases in northwest utility retail electricity rates which could erode the economic development advantage low rates has given our region for many years.
4) Energy production from wind farms in the PNW is often high during periods of maximum
hydro generation contributing to energy gluts that can drive short-term market prices to
zero or even to negative values due to federal tax credits received by wind power. To
minimize the net cost of hydro generation the region needs for year-round flexible and
reliable electricity, the value of surplus hydro energy sales needs to be maximized. Building
more wind farms in the PNW will contribute to untimely energy supply gluts and low short-
term market prices which reduces surplus hydro energy sales revenues, increases net hydro
power costs and puts upward pressure on retail rates Benton PUD and other utilities charge
our customers.
5) Benton PUD believes the best long-term, sustainable and environmentally responsible
strategy toward meeting the CETA goal of 100% clean electricity in Washington State by
2045 could be to transition coal power to natural gas and then natural gas to nuclear. It is
estimated wind power requires 30 to 45 times as much land and about 10 times as much
concrete and steel to produce the equivalent power of nuclear. In addition, a recent study
estimates that assuming hydro and nuclear power in the PNW stay in place, meeting a
theoretical 100% clean electricity goal in our region using wind (and solar) power would
require a land area 20 to 100 times the area of Seattle and Portland combined.
6) Benton PUD supports Energy Northwest (EN) in their efforts to develop small modular
reactor (SMR) technology. However, we are concerned continued large-scale investments
in PNW wind power projects will contribute to increases in the normally surplus annual
energy supplies in the region thereby eroding the hourly energy supply opportunities
needed by SMRs to achieve economic feasibility. Maintaining the existing Columbia
Generating Station operations while expanding SMR technology development and possible
manufacturing in the Tri-Cities represent opportunities for economic stability and growth in
an area with a long history of grid-scale energy production and world class scientific
research capabilities.
As some legislators and certain advocacy groups continue to call for more wind power while
simultaneously calling for removal of hydro-electric dams, Benton PUD believes it is important
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for our customers and citizens of Washington State to hear the utility side of the energy story.
To this end, we are committed to facilitating education and outreach efforts based on the
premise that all energy choices represent economic and environmental tradeoffs and that
consideration of utility business models and the physics of the power grid matter when taking a
position to promote one form of power generation technology over another.
Existing wind farm development in Washington State and along the northern Oregon border
has already resulted in the industrialization of previously scenic hillsides, canyons and desert
vistas in the region in and around Benton County. Before Benton PUD customers and citizens
throughout our region accept further sacrifice of the natural beauty and open spaces that are
part of our way of life, we want them to know there are other options we should be asking our
legislators and utility industry leaders to urgently and seriously consider. This is the reason for
this report and for our formal declaration that Benton PUD does not support further
development of wind power in the PNW.
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Existing Power Resources and Loads
Despite clean energy policies and trends favoring wind and solar power, continued
development of wind farms in the northwest is not expected to be necessary or beneficial to
serving the interests of Benton PUD customers for at least the next decade or more. This is
primarily due to our hydro and nuclear rich wholesale power supply contract with the
Bonneville Power Administration (BPA) which entitles Benton PUD to annual energy amounts
that are normally greater than what is consumed by our customers. In addition, our BPA
contract in combination with other energy purchases and contracts results in a power supply
that is already over 93% “non-emitting” and clean by Washington State standards.
With this said, it is important to recognize Benton PUD does face significant power supply
challenges under the terms and conditions of our current BPA contract. These challenges are
rooted in the timing of BPA energy delivery which does not always align with our customer
demand for electricity. Benton PUD is a “summer peaking” utility with our highest customer
demand being driven by irrigated-agriculture pumping operations combined with high
residential and business air conditioning; see FIGURE 1.
FIGURE 1
As a “Slice” customer of BPA, Benton PUD has rights to a fixed percentage of the electricity
generated by BPA resources for any given hour of the year which can be highly variable. As BPA
resources are predominantly hydro-electric, the variability is driven by the timing and quantity
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of runoff from snowpack as well as short term precipitation events which must be managed to
serve interests that compete with power generation; including fish and wildlife, flood control,
river navigation and recreation.
To gain further perspective, it is instructive to know that Benton PUD’s annual allocation of BPA
wholesale energy in typical water years delivers about 225 average megawatts (aMW) which is
more than our total annual customer retail energy consumption forecast beyond the year 2030.
On average, our BPA supply is currently 11 aMW more than our customers consume on an
annual basis. However, while Benton PUD currently has a “long” annual energy supply position,
we do experience regular seasonal energy supply deficits in the summer and on occasion can
come up short during deep cold periods in the winter. These seasonal energy supply shortfalls,
referred to as capacity deficits, are a function of Benton PUD’s dependence on the availability
of “fuel” (river flows) for BPA’s hydro resources which can vary significantly from year-to-year
and month-to-month; see FIGURE 2.
FIGURE 2
Under Benton PUD’s Slice contract with BPA, they are required to guarantee delivery of firm
monthly energy represented by the combined total of a “Block” and “Critical Slice” amount.
The “Above Critical Slice” is the amount of energy BPA is forecasting will be available to Benton
PUD but not guaranteed. Slice customers can re-sell surplus energy received from BPA when
supply exceeds what is required to serve customer loads but in return must accept and
independently manage the risk that loads may be higher than the available BPA supply.
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Any forecasted capacity deficits require Benton PUD to make purchases from wholesale
electricity markets in order to augment our long-term power supply contracts. Consequently,
we have people, processes and contracts in place to be sure our customer electricity demand is
completely supplied on an hourly and around the clock basis. Benton PUD’s wholesale
electricity purchases are typically made in short-term monthly, weekly, day-ahead and hourly
markets from generation resources that can be counted on to run on the days and hours
needed (dispatchable). These dispatchable generation resources provide needed capacity to
cover energy supply deficits that occur on the hottest and coldest days of the year.
Since wind power relies on natural weather conditions decoupled from electricity demand, it is
not a dispatchable generation resource and therefore development of more wind power will
not help Benton PUD resolve our seasonal capacity deficit problems; particularly our most
acute deficits which occur in summer months with very low levels of wind. We are also
concerned that preferences for wind power risk under investment in dependable and
dispatchable natural-gas generation plants most utilities believe will be essential for replacing
the capacity of coal-fired plants being rapidly retired and shut down in the Pacific Northwest
and throughout the western United States.
While wind energy developed on a large scale can be a substitute for much of the annual
energy produced by fossil-fueled power plants, it cannot provide the equivalent capacity
required for balancing electricity supply and demand on an around the clock basis, and under a
wide variety of weather conditions. Because the northwest is so dependent on the availability
of water for hydro-electric generation, the coldest and hottest days of a year in which water
resources are at a critically low level are of particular concern for electric utilities and is why
other reliable and dispatchable generation must be standing by and ready to run on demand.
When power grid supply does not meet demand on a moment-by-moment basis, blackouts can
occur. Benton PUD is concerned that a deepening dependence on wind power as a
replacement for energy produced by coal plants in the northwest could have serious
consequences in the not-too-distant future if grid operators are faced with the simultaneous
occurrence of drought conditions (low hydro power production), extreme temperatures, low
wind and not enough dispatchable electricity generators to meet peak customer demands.
To gain further perspective, it is also instructive to consider Benton PUD’s 11 aMW “long” BPA
annual energy position in the context of customer growth which is currently forecasted to
result in an increase of about 0.4 aMW of energy consumption per year. This relatively low
growth rate is driven by our continued investments in effective conservation measures as well
as improvements in the energy efficiency of new homes and businesses. In the simplest
analysis, Benton PUD’s expected annual supply of BPA power represents over 27 years of
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customer growth which means we are not currently looking to add substantial amounts of
“baseload” annual energy to our power supply portfolio from wind power or other resources.
With this said, new large loads associated with electricity intensive businesses or industry
locating in Benton PUD’s service territory are a wild card that could require acquisition of new
generation resources. Another resource acquisition driver could be preferences for wind and
solar power which are often used to brand businesses as sustainable. In either case, given the
requirements of Washington State’s Clean Energy Transformation Act (CETA) and other clean
energy policies and preferences in adjacent states and regions, wind and solar power may be
the only significant energy resources available to meet a future Benton PUD need. While not
ideal, we would choose solar power over wind given that solar energy production curves are
better aligned with our summer peaking load profile and would contribute to reducing our
regular summer capacity deficits on most days.
Existing Wind Power Resources Currently, Benton PUD’s power supply portfolio includes wind energy through direct contracts
from the Nine Canyon (9 MW) and White Creek (9.1 MW) projects delivering about 5.7 aMW of
total energy on an annual basis. These contracts were initiated by Benton PUD in response to
the qualifying renewable energy requirements of Washington State’s Energy Independence Act
(EIA) which initially did not include energy from existing hydro generation.
In addition to direct wind power purchases, Benton PUD’s contract with BPA includes an
allocation of about 1.4 aMW of their wind portfolio’s annual energy production. All the wind
resources in Benton PUD’s portfolio along with BPA’s hydro generation resulting from
incremental improvements to turbine-generator efficiency (incremental hydro) are considered
EIA qualifying renewable energy. This means energy from these resources provide a renewable
energy credit (REC) for every megawatt-hour of electricity generated.
REC allocations and purchases are how Benton PUD meets the renewable portfolio standard
(RPS) currently required by EIA mandates. In 2020 Benton PUD will need a total of about 30
aMW of REC allocations and purchases each year to meet the current 15% RPS requirement.
We plan to meet our compliance requirement with 7.1 aMW of total wind power RECs from
Nine Canyon, White Creek and BPA; 2.6 aMW of BPA incremental hydro REC allocations; and
20.4 aMW of REC purchases from other entities, including wind farms.
It is important to emphasize that a REC is a certificate corresponding to the environmental
attributes of energy produced from qualifying renewable resources and does not necessarily
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represent purchases of physical electricity. While Benton PUD has contractual rights to the
electricity produced by the Nine Canyon and White Creek projects, it is usually surplus to our
annual customer energy requirements except under a worst-case low hydro generation
scenario.
With that said, Benton PUD’s share of Nine Canyon’s physical electricity is always scheduled to
supply our load with the net effect during low customer load periods of increasing our BPA
hydro surplus which we sell in regional wholesale electricity markets. Due to power scheduling
complexities, Benton PUD’s share of the White Creek project’s physical electricity is bundled
with other utility shares and sold to another counterparty at a price currently well below the
relevant market power index. This below index pricing is an indicator of the reduced value of
wind energy compared to other more dependable generation resources.
Revenues from the sales of physical electricity attributed to Nine Canyon and White Creek are
considered as offsets to the total annual cost of Benton PUD’s EIA renewable-energy
compliance which is budgeted to be $3.8 million in 2020. We expect to continue to rely on REC
purchases as the primary means for meeting EIA mandates with some relief possible in 2030,
depending on CETA rules which are currently under development.
Benton PUD considers the incremental cost and dependence we have on continued operation
and development of wind and solar power for REC purchases as a perverse outcome of EIA
mandates given our extraordinarily clean power supply and surplus annual hydro and nuclear-
based energy position.
Surplus Energy and Market Sales
With respect to Benton PUD’s net annual surplus of energy, it is important to understand the
timing of when most surplus hydro generation occurs. For Benton PUD, the best combination
of market price and volume of surpluses occurs in January through March with the highest
volume and lowest prices occurring in April and May. When our hydro supply exceeds customer
demand, our BPA contract allows us to sell the surplus energy into wholesale electricity
markets. The revenues generated by our sales have the effect of buying down our annual
wholesale power costs.
Energy production from wind farms in the northwest can also be high during periods of
maximum hydro generation contributing to energy gluts that can drive market prices to zero or
even to negative values due to federal tax credits received by wind power. The wholesale
electricity market distortions created by wind power tax credits combined with the availability
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of abundant and low-priced natural gas has driven market prices to very low levels in recent
years. Consequently, the value of Benton PUD surplus hydro energy sales has been significantly
reduced from over $50 million in 2008 to under $20 million today.
While there are efforts underway centered on possible expansion of the Western Energy
Imbalance Market (EIM) to an extended day ahead market (EDAM) that could increase the
economic value of BPA hydro flexibility and capacity, Benton PUD believes further development
of wind power in existing “energy only” wholesale markets will continue to contribute to the
devaluation of hydro. To be clear, Benton PUD believes abundant and low-cost natural gas has
been the major driver of wholesale electricity price reductions but building more wind farms
will contribute to downward pressure on prices.
Overall, the erosion of the market value of hydro energy has resulted in upward pressure on
the prices BPA charges Benton PUD and consequently on the retail rates we charge our
customers. Since 2007, BPA’s revenues derived from market sales have dropped from over
$400 million to under $200 million in some years which leaves them looking to their ratepayers
to make up the difference. Benton PUD’s net power supply costs are budgeted to be $84
million in 2020 which is up 40% since 2010 when actual costs were $60 million.
Oversupply and Curtailments
Additional concerns regarding the development of more wind power are oversupply and
curtailments which are well described in a report developed by Harvard University for the
Bonneville Power Administration in May 2018.1
…As more intermittent renewable energy is added to the grid it creates oversupply,
particularly during low demand hours, when generation exceeds load. Oversupply causes
low or negative prices for wholesale energy during periods of overgeneration. When
scheduled generation exceeds scheduled demand in the hour-ahead market, the price of
energy falls below zero in an attempt to balance supply and demand. After accounting
for changes in generation and load between the hour-ahead and real-time markets, if
generation still exceeds load and there are no more generators willing to receive
payments to reduce their output, then balancing authorities must order generators to
curtail output to maintain system frequency. Negative bids often represent the lost
opportunities for the generator to take advantage of tax credits for renewable energy
production.
1 Patricia Florescu and Jack Pead, “Realizing the Value of Bonneville Power Administration’s Flexible Hydroelectric Assets”, 12, 13, 14, Mossavar-Rahmani Center for Business & Government, Harvard University, May 2018.
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…Due to the Pacific Northwest’s reliance on hydroelectricity, oversupply becomes more
problematic in the springtime when both river flows and wind generation are high.
Under those circumstances, extra water can be spilled from the dams so that it does not
contribute to oversupply, but too much spill exceeds water quality standards and can
harm fish and other aquatic species. If water cannot be spilled, it must be passed
through the hydropower turbines, thus generating electricity.
For conditions like these, BPA implemented the Oversupply Management Protocol, under
which non-hydrogeneration is displaced to protect aquatic life and maintain system
reliability. Displacement decisions are made according to a least-cost displacement cost
curve that lists generation in order of cost, from the least cost facility to the highest-cost
facility, until the required displacement quantity is achieved.53 After a federal court case
concluded in 2011, BPA enacted a new protocol that compensated wind generators for
lost revenues from curtailment and assigned the costs of curtailing generation during
oversupply events to BPA transmission customers.54
While Oversupply Management Protocol costs have not been extremely high2 relative to other
costs incurred by Benton PUD through our BPA transmission contract, we are concerned more
wind power on the grid will contribute to increases in BPA costs and will add more complexity
to the already difficult balancing act of managing river flows to meet the competing interests of
power generation, environmental stewardship, barging operations, flood control and
recreation.
Pacific Northwest Resource Adequacy Challenges
The Pacific Northwest’s clean hydroelectric generation resources are unmatched anywhere in
the United States and are the primary reason Washington State contributed on average no
more than 0.5% to the nation’s annual total greenhouse gas emissions from electricity
production each year between 1980 and 20173; even with coal plants in the mix.
While our already clean electricity sector is the envy of the nation, policy makers in Washington
State have set the course for 100% clean by 2045 through passage of the Clean Energy
Transformation Act (CETA). While a long-term goal like this is clearly aspirational at this point,
2 BPA’s displacement costs of OMP were around $4.87 million in 2018 and $2.2 million in 2017 https://www.bpa.gov/Projects/Initiatives/Oversupply/Pages/Annual-Oversupply-Review.aspx. 3U.S. Energy Information Administration, “State Carbon Dioxide Emissions Data” https://www.eia.gov/environment/emissions/state/.
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the near-term consequences of CETA’s underlying requirements are significant and very
concerning when it comes to maintaining power grid reliability. The most consequential
requirements are the explicit removal of coal power from utility portfolios by 2025 and the
“social cost of carbon” which must be used as a cost adder when utilities evaluate investments
in new generation resources. As intended by legislators, this cost adder will have a chilling
effect on investments to construct new natural-gas power plants which utilities would normally
consider to be the logical replacement for dispatchable capacity associated with retiring coal
plants.
Unfortunately, CETA along with other anti-fossil-fuel sentiment in Oregon and California energy
policies has put northwest utilities in a position where it appears only wind and solar power
along with batteries, pumped hydro and customer load curtailments (demand response) will be
allowed to try and solve utility capacity deficits. The problem is that science, economics and
project development cycle times indicate the politically preferred technologies are not ready to
provide solutions at the scale needed to mitigate the already unacceptable increase in the risk
of blackouts projected for the Pacific Northwest beginning in 20214. In their most recent
assessment, the Northwest Power and Conservation Council (NWPCC) estimates that
accelerated coal-plant retirements could increase the likelihood that generating capacity will
not be adequate for meeting demand to a level of 26% by 2026. This is well above the 5%
threshold established as the limit for an adequate regional power supply.
Benton PUD is a relatively small player in the northwest grid, but our seasonal capacity deficits
are significant. This is why we joined forces with other members of the Public Generating Pool
(PGP) and several investor owned utilities to co-fund a study by E3 Consulting5 of what will be
required to maintain power grid reliability in the Pacific Northwest while further de-carbonizing
the electricity sector. This study found that deep de-carbonization is possible but that natural
gas fired generation will be needed to maintain power grid reliability; it would just run
infrequently.
While development of wind farms may be politically fashionable and appeal to many in the
general public as a harmonization of nature with electricity production, the science and
economics indicate powering modern civilization with intermittent generation resources like
wind and solar power comes at a high financial and environmental cost. E3’s study concludes
that increasing the Pacific Northwest’s inventory of wind power from the 2018 level of 7
4 Northwest Power and Conservation Council, “Pacific Northwest Power Supply Adequacy Assessment for 2024”: October 2019. 5 Energy+Environmental Economics, “Resource Adequacy in the Pacific Northwest”: Public Generating Pool, March 2019.
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gigawatts to a level of 38 gigawatts by 20506 would only result in an effective capacity
contribution from wind of 19%. In other words, a more than fivefold investment in wind power
which E3 estimates would cover an area as much as 37 times the combined areas of Seattle and
Portland, would only allow regional utilities to count on 19% of the capital investment to
produce electricity when it is most critically needed. The E3 study also estimates the area
required to achieve a theoretical 100% clean electricity sector in the northwest using only wind
and solar power (assuming existing hydro and nuclear stay in place) would require a land area
as much 100 times the combined areas of Seattle and Portland.
On November 12, 2019 Benton PUD Commissioners adopted Resolution 2523 in support of
actions to ensure electric sector resource adequacy in the Pacific Northwest. This resolution
provides a sound argument for why northwest utilities have serious concerns regarding the
reliability of the northwest power grid and why Benton PUD questions the wisdom of continued
development of large numbers of wind farms in our region when we are facing potentially
serious consequences associated with power grid blackouts.
Other Considerations
The “fuel” for wind power is dilute and intermittent requiring additional investments in backup
generation technologies to meet the always-on requirements of power grids. While developers
and advocates often tout continued reductions in the cost of wind energy, the low availability
of wind power requires utilities to continue paying for dispatchable generation capacity that
may run infrequently but is sized to meet most of the peak energy demand on the grid. This
“double paying” is why electricity rates in countries and states with high wind penetrations
have risen significantly amid claims of low-cost renewable energy.
CETA together with the Energy Independence Act (EIA) appears to have established an
undefined increase in Washington State’s renewable portfolio standard (RPS) which will
undoubtedly lead to some level of double paying in Washington State. Establishing preferences
for wind and solar energy with no accompanying targets for greenhouse gas (GHG) emission
reductions in the electricity sector has been shown through comprehensive study to result in
unnecessary increases in the cost of electricity while not reducing GHG emissions in the most
cost-effective manner possible7.
6 38 gigawatts of nameplate wind power capacity is what E3 determined would be required in an optimal scenario to reduce greenhouse gas emissions from electricity production by 80% below 1990 levels; an often-quoted goal from the Intergovernmental Panel on Climate Change (IPCC). 7 Energy+Environmental Economics, “Pacific Northwest Low Carbon Scenario Analysis - Achieving Least-Cost Carbon Emissions Reductions in the Electricity Sector”: Public Generating Pool, December 2017.
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Additionally, the land area required for wind turbine construction and transmission lines
needed for grid interconnections can be immense and the negative ecological and
environmental impacts of this “energy sprawl” may outweigh the perceived or real benefits.
Benton PUD believes lifecycle economic and environmental impacts expected to result from
further development of wind power need to be scrutinized to a much higher degree with
greater recognition of issues like the global impacts of raw materials mining and the disposal of
wind turbine blades which are currently destined for landfills.
Benton PUD acknowledges every source of energy production takes a toll on the environment
but believes wind power is often given a pass due to its popularity with policy makers and many
in the general public. One source estimates wind power requires about 30 to 45 times as much
land to produce a comparable amount of power as nuclear and that concrete and steel
requirements for wind are about 10 times greater8. We believe these are important and
relevant considerations as investments are made in power generation projects that will have
long lasting environmental and financial impacts.
Benton PUD supports provisions of CETA that count hydro and nuclear energy toward the 100%
clean by 2045 objective. However, we believe a more cost-effective and potentially less risky
trajectory toward this goal would have been to allow for the transition from coal to natural gas
and to promote an increase in the development of nuclear energy as the best long-term and
sustainable strategy. We believe it is reasonable to suggest the most balanced and
environmentally responsible actions you can take to “clean up” the electricity sector is to
produce as much low or non-emitting electricity as possible in the smallest area possible. This
seems to be best accomplished with energy dense fuels like natural gas and uranium.
Benton PUD supports EN in their efforts to develop small modular reactor (SMR) technology.
However, we are concerned continued large-scale investments in wind power will substantially
increase the normally surplus annual energy supplies in the Pacific Northwest (PNW) thereby
eroding the hourly energy supply opportunities needed by SMRs to achieve economic
feasibility. According to the Bonneville Power Administration (BPA)9 the generating potential
from federal and non-federal hydro projects in the PNW can vary by almost 7,000 aMW
annually and by almost 14,000 aMW in some months, depending on project operations and the
availability of water. But even in the worst water years, the PNW region is projected to have
annual firm energy surpluses for the next ten years, assuming the region’s 4,000 MW of
uncommitted independent power producer (IPP) generation capacity is available to serve
regional loads. Adding to this “long” regional energy position with continued development of
8 Robert Bryce, “Power Hungry – The Myths of “Green” Energy and the Real Fuels of the Future”: Pages 84, 91. 9 Bonneville Power Administration, “2018 Pacific Northwest Loads and Resources Study”: April 2019, Section 3.
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large-scale wind farms does not bode well for the development of SMR based generating
projects given their relatively high capital costs and the need for lots of run time in order to
reduce energy production costs to levels that will make them competitive with other
technologies.
Conclusions
It appears additional wind farm development in the Pacific Northwest (PNW) is gaining
momentum and is a foregone conclusion in the minds of many legislators, members of the
general public and even some utilities. Benton PUD believes it is reasonable to question
whether continuing to favor investments in intermittent wind power and putting up roadblocks
to the development of dispatchable natural-gas power plants is more about environmental
virtue signaling than it is about serving the best interests of the citizens of Washington State.
There is no denying the fact that thanks to abundant PNW hydro energy, Washington State has
historically been one of the lowest contributors to electricity sector greenhouse gas (GHG)
emissions in the United States and that electricity sector contributions to total statewide GHG
emissions have been only 16 to 19%10, even with coal plants in the mix. Put another way, what
urgent “dirty energy” problem are we attempting to solve through the aggressive timelines and
technology restrictions of the Clean Energy Transformation Act (CETA) that is worth sacrificing
vast amounts of our natural landscapes and risking blackouts that jeopardize the health, safety
and wellbeing of northwest electricity customers?
While language exists within CETA requiring future reporting to the governor’s office to address
concerns with power grid reliability, it appears legislators do not believe the risk of blackouts is
real. If they did, they would accept the results of already existing utility studies and
immediately begin to work on modifications to CETA to remove disincentivizes for the
development of dispatchable natural gas plants needed for replacing retiring coal-plant
capacity. So, at this point, investor owned utilities are announcing plans for new wind power
projects to meet CETA deadlines, and along with all northwest utilities, are hoping the efforts of
the Northwest Power Pool (NWPP) to develop power-generation resource adequacy standards
can be completed and implemented in time to avoid blackouts11.
Benton PUD strongly supports the efforts of the NWPP, but we do not support further
development of wind power in the PNW. We believe continued investments in large-scale wind
farm development in the PNW will: (1) contribute very little to keeping the regional power grid
10 Department of Ecology State of Washington, “Washington State Greenhouse Gas Emissions Inventory: 1990-2015 Report to the Legislature,”: December 2018, Publication 18-02-043, Pg. 6, Table 2. 11Northwest Power Pool Resource Adequacy: https://www.nwpp.org/about/workgroups/12
126
Wind Power and Clean Energy Policy Perspectives
Benton PUD - June 2020 Page 15 of 15
reliable and will not help Benton PUD solve our seasonal energy deficit problems; (2) contribute
to the devaluation of hydro-generation assets and put upward pressure on retail rates Benton
PUD and other utilities charge our customers; (3) risk underinvestment in needed dispatchable
capacity today and future investments in visionary advancements in nuclear energy technology;
(4) further sacrifice scenic hillsides, canyons and desert vistas in our region for little if any net
environmental benefit.
127
2018 2019 2020
Jan Feb Mar Apr May Jun Jan Feb Mar Apr May Jun Jan Feb Mar Apr May Jun
$0M
$2M
$4M
$6M
$8M
$10M
$12M
$ Amount
($3M)
($2M)
($1M)
$0M
$1M
$2M
Cumulative Variance (Line) / Monthly Variance (Bar)
$11.08M$10.44M
$11.99M
$9.38M $9.35M $9.15M
$10.23M
$11.15M $11.00M
$12.42M
$9.22M$9.82M
$10.48M $10.35M
$11.83M
$9.98M$9.49M
$9.98M
($0.63M)
($0.23M)($0.08M)
$0.05M
$0.50M$0.29M
($1.03M)
($0.27M)
($0.63M)
$0.92M
$1.97M
$0.06M
($1.13M)
($0.56M)($0.71M) ($0.78M)
$0.20M$0.37M
Cumulative Retail Revenue Budget vs Actuals: AllLegendActual
Budget
Month Over / (Under)
Cumulative Variance
128
2018 2019 2020
Jan Feb Mar Apr May Jun Jan Feb Mar Apr May Jun Jan Feb Mar Apr May Jun
$0M
$1M
$2M
$3M
$4M
$5M
$6M
$7M
$8M
$ Amount
($2M)
($1M)
$0M
$1M
$2M
Cumulative Variance (Line) / Monthly Variance (Bar)
$7.31M
$5.81M
$5.32M
$4.53M
$3.73M$4.10M
$6.60M
$7.44M $7.27M
$4.68M
$3.62M
$4.17M
$6.77M$6.31M
$5.19M$4.86M
$3.81M$4.19M
($0.09M)
($0.69M)
($0.08M)
$0.38M $0.37M
$0.04M
($1.00M)
($0.29M) ($0.27M)
$0.77M
$2.17M
$0.37M
($1.13M)
($0.62M)
($0.12M) ($0.16M)($0.31M)
$0.39M
Cumulative Retail Revenue Budget vs Actuals: Residential SalesLegendActual
Budget
Month Over / (Under)
Cumulative Variance
129
2018 2019 2020
Jan Feb Mar Apr May Jun Jan Feb Mar Apr May Jun Jan Feb Mar Apr May Jun
$0M
$ Amount
$0M
Cumulative Variance (Line) / Monthly Variance (Bar)
$0.88M
$0.78M
$0.70M $0.69M $0.70M
$0.77M
$0.83M
$0.91M
$0.85M
$0.70M $0.68M
$0.76M
$0.84M$0.81M
$0.69M
$0.64M
$0.58M
$0.65M
($0.02M)
$0.02M $0.03M $0.02M $0.01M $0.00M
($0.04M) ($0.04M) ($0.03M)
$0.09M
$0.16M
$0.02M
($0.06M)($0.03M)
($0.01M)
($0.06M)
($0.14M) ($0.14M)
Cumulative Retail Revenue Budget vs Actuals: Small General Service SalesLegendActual
Budget
Month Over / (Under)
Cumulative Variance
130
2018 2019 2020
Jan Feb Mar Apr May Jun Jan Feb Mar Apr May Jun Jan Feb Mar Apr May Jun
$0M
$1M
$ Amount
$0M
Cumulative Variance (Line) / Monthly Variance (Bar)
$1.17M
$1.07M
$0.99M$0.96M $0.96M
$1.02M
$1.13M$1.17M
$1.12M
$0.99M$0.93M
$1.03M
$1.15M$1.09M
$0.97M$0.91M
$0.87M
$0.94M
($0.06M)
$0.00M
$0.01M
$0.06M $0.06M$0.03M
($0.04M)($0.01M)
$0.04M
$0.13M$0.09M
$0.01M
($0.01M)($0.03M)
($0.09M)
($0.15M)($0.18M)
$0.00M
Cumulative Retail Revenue Budget vs Actuals: Medium General Service SalesLegendActual
Budget
Month Over / (Under)
Cumulative Variance
131
2018 2019 2020
Jan Feb Mar Apr May Jun Jan Feb Mar Apr May Jun Jan Feb Mar Apr May Jun
$0M
$1M
$ Amount
$0M
Cumulative Variance (Line) / Monthly Variance (Bar)
$1.24M $1.22M
$1.14M $1.11M$1.16M $1.17M
$1.21M$1.17M $1.15M
$1.10M $1.08M
$1.17M$1.23M $1.23M
$1.16M$1.11M
$1.04M$1.10M
$0.11M $0.11M $0.09M$0.14M
$0.16M
$0.10M$0.07M
$0.05M$0.10M
$0.12M
$0.04M $0.06M
($0.04M)
($0.15M)($0.17M)
$0.07M $0.08M $0.08M
Cumulative Retail Revenue Budget vs Actuals: Large General Service SalesLegendActual
Budget
Month Over / (Under)
Cumulative Variance
132
2018 2019 2020
Jan Feb Mar Apr May Jun Jan Feb Mar Apr May Jun Jan Feb Mar Apr May Jun
$0M
$1M
$2M
$3M
$4M
$5M
$ Amount
($1M)
$0M
Cumulative Variance (Line) / Monthly Variance (Bar)
$0.11M $0.16M
$0.83M
$1.46M
$3.45M
$4.40M
$0.12M $0.11M$0.24M
$1.36M
$3.05M
$4.79M
$0.12M $0.19M
$1.10M
$2.38M
$3.20M
$4.43M
($0.77M)
($0.13M)$0.00M
$0.02M $0.01M$0.06M
($0.02M)
($0.56M)
($0.80M)
($0.30M)
$0.00M
$0.34M
($0.10M)
$0.00M$0.06M
$0.28M$0.20M
$0.05M
Cumulative Retail Revenue Budget vs Actuals: Large Irrigation SalesLegendActual
Budget
Month Over / (Under)
Cumulative Variance
133
Date
Jun Jul
2 4 6 8 10 12 14 16 18 20 22 24 26 2830 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30
0K
20K
40K
60K
80K
100K
120K
140K
160K
180K
Running Sum of MWH
2018
2019
2018
2020
Billed Revenue ClassInOut
Revenue ClassAll
AMI data updated through:
Friday, July 3, 2020
Revenue Class Cumulative EnergyBy Year for Revenue Class: All in Month: June & July
Year ofDate MWH
MWHDifference
%Difference
2017
2018
2019
2020 -2.97%-5,380175,482
-1.59%-2,922180,862
2.50%4,481183,784
179,303
Select filters:Year Over Year Summary:(hover to highlight year)
Year of DateAll
Month of DateMultiple values
Month-DayMultiple values
Note:Totals do not includenon-AMI meter readings.
Abc
134
Date
Jun Jul
2 4 6 8 10 12 14 16 18 20 22 24 26 2830 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30
0K
5K
10K
15K
20K
25K
30K
35K
40K
45K
50K
55KRunning Sum of MWH
2020
20202018
2019
Billed Revenue ClassInOut
Revenue ClassResidentialSmall GeneralMedium GeneralLarge GeneralLarge IndustrialLarge IrrigationSmall Irrigation
AMI data updated through:
Friday, July 3, 2020
Revenue Class Cumulative EnergyBy Year for Revenue Class: Residential in Month: June & July
Year ofDate MWH
MWHDifference
%Difference
2017
2018
2019
2020 -1.26%-67853,052
5.17%2,64353,729
-3.96%-2,10551,086
53,191
Select filters:Year Over Year Summary:(hover to highlight year)
Year of DateAll
Month of DateMultiple values
Month-DayMultiple values
Note:Totals do not includenon-AMI meter readings.
Abc
135
Date
Jun Jul
2 4 6 8 10 12 14 16 18 20 22 24 26 2830 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30
0K
1K
2K
3K
4K
5K
6K
7K
8K
9K
10K
11K
Running Sum of MWH
2020
2019
2017
2020
2019
Billed Revenue ClassInOut
Revenue ClassResidentialSmall GeneralMedium GeneralLarge GeneralLarge IndustrialLarge IrrigationSmall Irrigation
AMI data updated through:
Friday, July 3, 2020
Revenue Class Cumulative EnergyBy Year for Revenue Class: Small General in Month: June & July
Year ofDate MWH
MWHDifference
%Difference
2017
2018
2019
2020 -12.77%-1,4469,882
2.24%24811,328
0.55%6111,080
11,019
Select filters:Year Over Year Summary:(hover to highlight year)
Year of DateAll
Month of DateMultiple values
Month-DayMultiple values
Note:Totals do not includenon-AMI meter readings.
No AMI readings for the NineCanyon Wind Project load. Abc
136
Date
Jun Jul
2 4 6 8 10 12 14 16 18 20 22 24 26 2830 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30
0K
2K
4K
6K
8K
10K
12K
14K
16K
18KRunning Sum of MWH
2019
2020
20172018
2020
2019
Billed Revenue ClassInOut
Revenue ClassResidentialSmall GeneralMedium GeneralLarge GeneralLarge IndustrialLarge IrrigationSmall Irrigation
AMI data updated through:
Friday, July 3, 2020
Revenue Class Cumulative EnergyBy Year for Revenue Class: Medium General in Month: June & July
Year ofDate MWH
MWHDifference
%Difference
2017
2018
2019
2020 -14.17%-2,42814,707
3.74%61917,136
-0.99%-16416,517
16,682
Select filters:Year Over Year Summary:(hover to highlight year)
Year of DateAll
Month of DateMultiple values
Month-DayMultiple values
Note:Totals do not includenon-AMI meter readings.
Abc
137
Date
Jun Jul
2 4 6 8 10 12 14 16 18 20 22 24 26 2830 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30
0K
2K
4K
6K
8K
10K
12K
14K
16K
18K
20K
22K
Running Sum of MWH
2018
2020
2020
2017
20192018
Billed Revenue ClassInOut
Revenue ClassResidentialSmall GeneralMedium GeneralLarge GeneralLarge IndustrialLarge IrrigationSmall Irrigation
AMI data updated through:
Friday, July 3, 2020
Revenue Class Cumulative EnergyBy Year for Revenue Class: Large General in Month: June & July
Year ofDate MWH
MWHDifference
%Difference
2017
2018
2019
2020 -16.80%-3,68018,221
-0.06%-1421,901
5.70%1,18221,915
20,733
Select filters:Year Over Year Summary:(hover to highlight year)
Year of DateAll
Month of DateMultiple values
Month-DayMultiple values
Note:Totals do not includenon-AMI meter readings.
Abc
138
Date
Jun Jul
2 4 6 8 10 12 14 16 18 20 22 24 26 2830 2 4 6 8 10 12 14 16 18 20 22 24 26 28 30
0K
10K
20K
30K
40K
50K
60K
70K
Running Sum of MWH
2018 2019
2020
2018
Billed Revenue ClassInOut
Revenue ClassResidentialSmall GeneralMedium GeneralLarge GeneralLarge IndustrialLarge IrrigationSmall Irrigation
AMI data updated through:
Friday, July 3, 2020
Revenue Class Cumulative EnergyBy Year for Revenue Class: Large Irrigation in Month: June & July
Year ofDate MWH
MWHDifference
%Difference
2017
2018
2019
2020 4.16%2,87671,930
-7.42%-5,53269,055
7.20%5,01174,586
69,575
Select filters:Year Over Year Summary:(hover to highlight year)
Year of DateAll
Month of DateMultiple values
Month-DayMultiple values
Note:Totals do not includenon-AMI meter readings.
No AMI readings for thepump decks at Spaw,Paterson #1 & #2 and Prior#1 Bay 1 & 2.
Abc
139
Past Due AR in Dollars for Selected Revenue Classes:
Month End Daily
03/31/19
06/30/19
09/30/19
12/31/19
03/21/20
03/24/20
03/27/20
03/30/20
04/02/20
04/05/20
04/08/20
04/11/20
04/14/20
04/17/20
04/20/20
04/23/20
04/26/20
04/29/20
05/02/20
05/05/20
05/08/20
05/11/20
05/14/20
05/17/20
05/20/20
05/23/20
05/26/20
05/29/20
06/01/20
06/04/20
06/07/20
06/10/20
06/13/20
06/16/20
06/19/20
06/22/20
06/25/20
06/28/20
07/01/20
07/04/20
07/07/20
$0K
$250K
$500K
$750K
$1,000K
$1,250K
Total AR ($)
AllBalance Aging: 30 Days | 60 Days | 90+ Days
AR data as of 7/8/20. Data source is CIS via the AR Balance History SQL report.
$333,119
$210,818
$412,917
$956,854
30 Days
60 Days
90+ Days
Past Due 4,548
1,628
824
2,096Accounts Dollars
49,4.. $9,120,24049,440Total AR
Revenue Class Selection:All
Consumer Class Selection:Regular
140
Past Due AR in Dollars for Selected Revenue Classes:
Month End Daily
03/31/19
06/30/19
09/30/19
12/31/19
03/21/20
03/24/20
03/27/20
03/30/20
04/02/20
04/05/20
04/08/20
04/11/20
04/14/20
04/17/20
04/20/20
04/23/20
04/26/20
04/29/20
05/02/20
05/05/20
05/08/20
05/11/20
05/14/20
05/17/20
05/20/20
05/23/20
05/26/20
05/29/20
06/01/20
06/04/20
06/07/20
06/10/20
06/13/20
06/16/20
06/19/20
06/22/20
06/25/20
06/28/20
07/01/20
07/04/20
07/07/20
$0K
$250K
$500K
$750K
$1,000K
Total AR ($)
ResidentialBalance Aging: 30 Days | 60 Days | 90+ Days
AR data as of 7/8/20. Data source is CIS via the AR Balance History SQL report.
$301,909
$188,931
$295,975
$786,815
30 Days
60 Days
90+ Days
Past Due 4,011
1,483
762
1,766Accounts Dollars
40,9.. $2,284,38140,914Total AR
Revenue Class Selection:Residential
Consumer Class Selection:Regular
141
Past Due AR in Dollars for Selected Revenue Classes:
Month End Daily
03/31/19
06/30/19
09/30/19
12/31/19
03/21/20
03/24/20
03/27/20
03/30/20
04/02/20
04/05/20
04/08/20
04/11/20
04/14/20
04/17/20
04/20/20
04/23/20
04/26/20
04/29/20
05/02/20
05/05/20
05/08/20
05/11/20
05/14/20
05/17/20
05/20/20
05/23/20
05/26/20
05/29/20
06/01/20
06/04/20
06/07/20
06/10/20
06/13/20
06/16/20
06/19/20
06/22/20
06/25/20
06/28/20
07/01/20
07/04/20
07/07/20
$0K
Total AR ($)
Small General ServiceBalance Aging: 30 Days | 60 Days | 90+ Days
AR data as of 7/8/20. Data source is CIS via the AR Balance History SQL report.
$20,966
$11,124
$58,614
$90,703
30 Days
60 Days
90+ Days
Past Due 296
75
33
188Accounts Dollars
4,924 $417,3274,924Total AR
Revenue Class Selection:Small General Service
Consumer Class Selection:Regular
142
Past Due AR in Dollars for Selected Revenue Classes:
Month End Daily
03/31/19
06/30/19
09/30/19
12/31/19
03/21/20
03/24/20
03/27/20
03/30/20
04/02/20
04/05/20
04/08/20
04/11/20
04/14/20
04/17/20
04/20/20
04/23/20
04/26/20
04/29/20
05/02/20
05/05/20
05/08/20
05/11/20
05/14/20
05/17/20
05/20/20
05/23/20
05/26/20
05/29/20
06/01/20
06/04/20
06/07/20
06/10/20
06/13/20
06/16/20
06/19/20
06/22/20
06/25/20
06/28/20
07/01/20
07/04/20
07/07/20
$0K
Total AR ($)
Medium General ServiceBalance Aging: 30 Days | 60 Days | 90+ Days
AR data as of 7/8/20. Data source is CIS via the AR Balance History SQL report.
$7,633
$8,440
$41,159
$57,232
30 Days
60 Days
90+ Days
Past Due 29
7
6
16Accounts Dollars
787 $632,032787Total AR
Revenue Class Selection:Medium General Service
Consumer Class Selection:Regular
143
Past Due AR in Dollars for Selected Revenue Classes:
Month End Daily
03/31/19
06/30/19
09/30/19
12/31/19
03/21/20
03/24/20
03/27/20
03/30/20
04/02/20
04/05/20
04/08/20
04/11/20
04/14/20
04/17/20
04/20/20
04/23/20
04/26/20
04/29/20
05/02/20
05/05/20
05/08/20
05/11/20
05/14/20
05/17/20
05/20/20
05/23/20
05/26/20
05/29/20
06/01/20
06/04/20
06/07/20
06/10/20
06/13/20
06/16/20
06/19/20
06/22/20
06/25/20
06/28/20
07/01/20
07/04/20
07/07/20
$0K
Total AR ($)
Large General ServiceBalance Aging: 30 Days | 60 Days | 90+ Days
AR data as of 7/8/20. Data source is CIS via the AR Balance History SQL report.
$0
$0
$180
$180
30 Days
60 Days
90+ Days
Past Due 1
1Accounts Dollars
166 $852,319166Total AR
Revenue Class Selection:Large General Service
Consumer Class Selection:Regular
144
Past Due AR in Dollars for Selected Revenue Classes:
Month End Daily
03/31/19
06/30/19
09/30/19
12/31/19
03/21/20
03/24/20
03/27/20
03/30/20
04/02/20
04/05/20
04/08/20
04/11/20
04/14/20
04/17/20
04/20/20
04/23/20
04/26/20
04/29/20
05/02/20
05/05/20
05/08/20
05/11/20
05/14/20
05/17/20
05/20/20
05/23/20
05/26/20
05/29/20
06/01/20
06/04/20
06/07/20
06/10/20
06/13/20
06/16/20
06/19/20
06/22/20
06/25/20
06/28/20
07/01/20
07/04/20
07/07/20
$0K
$250K
Total AR ($)
IrrigationBalance Aging: 30 Days | 60 Days | 90+ Days
AR data as of 7/8/20. Data source is CIS via the AR Balance History SQL report.
$0
$0
$8,927
$8,927
30 Days
60 Days
90+ Days
Past Due 61
61Accounts Dollars
228 $4,442,771228Total AR
Revenue Class Selection:Irrigation
Consumer Class Selection:Regular
145
1. AR Data as of 7/8/20.2. References to Total represent the total in the report and may differ slightly from the sum of the categories due to rounding.3. Examples of Information & Government businesses include government agencies and telecommunications.4. Examples of Services - General businesses include automotive shops, consultants, cleaners, and real estate.5. Examples of Services - Personal include gyms and salons.
Agriculture,Construction &Manufacturing
Food Services Health Care Hospitality Information &Government
Retail Trade Services -General
Services -Personal
$0K
$10K
$20K
$30K
$40K
$50K
$60K
Past Due AR ($)
Past Due AR in Dollars for Business CategoriesSmall, Medium, and Large General Service
Past Due Balance Aging: 30 Days | 60 Days | 90+ Days
Category # of Accounts# of Accounts(% of Total)
Total AR Total AR(% of Total)
Past Due AR 30 Day AR 60 Day AR 90+ Day AR
Agriculture, Construction& Manufacturing
Food Services
Health Care
Hospitality
Information &Government
Retail Trade
Services - General
Services - Personal
Total $28,599
$6,212
$3,820
$6,989
$163
$186
$0
$9,078
$2,152
$19,564
$5,041
$2,799
$3,303
$226
$525
$0
$6,843
$826
$99,952
$4,558
$16,802
$4,547
$58,811
$1,510
$433
$11,349
$1,944
$148,115
$15,811
$23,421
$14,840
$59,200
$2,220
$433
$27,269
$4,922
100%
8%
13%
8%
50%
2%
0%
16%
3%
$252,447
$19,996
$33,212
$19,705
$126,825
$3,842
$787
$40,739
$7,341
100%
13%
17%
12%
39%
2%
1%
13%
3%
326
43
55
39
128
6
4
41
10
146
Past Due Accounts by Dollar Amount Range (as of 7/8/2020)# of Accounts | $ Amount
Accounts are sorted into past due amount ranges listed across the bottom.Each range is lableled by the maximum value; the minimum value begins where the previous range leaves off.
<$100 <$200 <$300 <$400 <$500 <$600 <$700 <$800 <$900 <$1,000 <$1,500 <$2,500
0
200
400
600
800
1000
1200
1400
1600
$91,795
$151,704
$114,826$116,864
$97,518
$59,925
$49,236
$33,161$30,533
$15,238
$23,784
$2,232
Consumer Class Selection:PrepaidRegular
Revenue Class Selection:IrrigationLarge General ServiceMedium General ServiceResidentialSecurity LightingSmall General ServiceSmall Irrigation
Customers Accounts Past Due
Residential
Total $786,815
$786,815
4,011
4,011
3,852
3,852# of Accounts
147
Past Due Accounts by Dollar Amount Range (as of 7/8/2020)# of Accounts | $ Amount
Accounts are sorted into past due amount ranges listed across the bottom.Each range is lableled by the maximum value; the minimum value begins where the previous range leaves off.
<$100 <$200 <$300 <$400 <$500
0
2
4
6
8
10
12
14
16
18
$727
$2,479
$1,467
$1,649
$444
Consumer Class Selection:PrepaidRegular
Revenue Class Selection:Residential
Customers Accounts Past Due
Residential
Total $6,766
$6,766
42
42
41
41# of Accounts
148
Past Due Accounts by Dollar Amount Range (as of 7/8/2020)# of Accounts | $ Amount
Accounts are sorted into past due amount ranges listed across the bottom.Each range is lableled by the maximum value; the minimum value begins where the previous range leaves off.<$100
<$200
<$300
<$400
<$500
<$600
<$700
<$800
<$900
<$1,000
<$1,500
<$2,000
<$2,500
<$4,500
>=$4500
0
10
20
30
40
50
60
70
80
90
100
110
$4,973
$8,127
$12,042
$8,795
$7,479
$5,421 $5,137
$6,666
$5,880
$4,798
$20,904
$11,067
$6,332
$19,827
$20,668
Consumer Class Selection:Regular
Revenue Class Selection:IrrigationLarge General ServiceMedium General ServiceResidentialSecurity LightingSmall General ServiceSmall Irrigation
Customers Accounts Past Due
Small General Service
Medium General Service
Large General Service
Total $148,115
$180
$57,232
$90,703
326
1
29
296
175
1
23
156# of Accounts
149
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