HomeMy WebLinkAboutCOUNCIL - AGENDA ITEM - 11/15/2016 - ITEMS RELATING TO 2017 UTILITY RATE ORDINANCESAgenda Item 6
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AGENDA ITEM SUMMARY November 15, 2016
City Council
STAFF
Lance Smith, Utilities Strategic Finance Director
SUBJECT
Items Relating to 2017 Utility Rate Ordinances.
EXECUTIVE SUMMARY
A. Second Reading of Ordinance No. 122, 2016, Amending Chapter 26 of the Code of the City of Fort Collins
to Revise Electric Rates, Fees and Charges.
B. Second Reading of Ordinance No. 123, 2016, Amending chapter 26 of the Code of the City of Fort Collins
to Revise Water Rates, Fees and Charges.
C. Second Reading of Ordinance No. 124, 2016, Amending Chapter 26 of the Code of the City of Fort Collins
to Revise Wastewater Rates, Fees and Charges.
D. Second Reading of Ordinance No. 125, 2016, Amending Chapter 26 of the Code of the City of Fort Collins
to Revise Stormwater Rates, Fees and Charges.
These Ordinances, unanimously adopted on First Reading on November 1, 2016, adopt rate changes for
electric, water, wastewater and stormwater monthly charges, beginning in January 2017. The proposed rate
increases for 2017 and 2018, as well as the primary driver behind the requested increases, are outlined in the
table below.
Proposed Revenue Adjustments
Utility Service 2017 2018
Electric 3.45% 1.80%
Water 5.00% 5.00%
Wastewater 3.00% 3.00%
Stormwater 5.00% 0.00%
In Ordinance No. 122, 2016, Electric Rates, the language initially adopted on First Reading has been removed
from Sections 2 and 3. The removed language involved proposed additions to City Code Sections 26-464(r)
and 26-465(r) expanding the scope of “community solar projects” to include low-income solar program
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installations. The full program details, including a version of the proposed language removed from Ordinance
No. 122, 2016, will return for Council consideration in 2017.
STAFF RECOMMENDATION
Staff recommends adoption of the Ordinances on Second Reading.
BACKGROUND / DISCUSSION
In addition to the material provided on First Reading, the following materials were also requested for Second
Reading:
1. Historical data on previous rate increases (20 years) (Attachment 2)
2. Report on the Westminster Valuation of Water Conservation (Attachment 3)
3. More details on the materials presented to the Council Finance Committee including:
a. What is in the 10 year Capital Improvement Plans (Attachments 4 and 5)
b. What is the difference between limiting rate increases to 3% rather than 5%
1. Historical Rate Increases
Attachment 2 shows historical comparisons of the utility rate increases compared to national utility rate trends,
the local Consumer Price Index, and trends in the cost of Housing in Fort Collins and Larimer County Personal
Income. Attachment 2 includes 2 graphs for each utility service. The first chart shows the cumulative rate
increase relative to standard benchmarks and the second shows the magnitude and occurrence of each rate
adjustment. It also includes 3 charts comparing all four utilities to each financial metric.
Electric and water rates have increased slower than Fort Collins Housing and Larimer County Personal
Income. Wastewater and Stormwater have increased faster than both of these metrics over the same 20 year
period. The net effect to the typical utility bill has been an increase that has grown faster than the Boulder-
Greeley CPI, slower than Fort Collins Housing and at the same rate as the Larimer County Personal Income.
2. Westminster Valuation of Water Conservation
Attachment 3 describes how the City of Westminster assessed the benefits of water conservation by its
customers over the past 30+ years. The finding is that water and wastewater rates would be considerably
higher and that additional capital investment would have been required to serve the community without the
realized conservation of water over this time period. Similar results would be expected for Fort Collins
although much of our realized conservation occurred just after the last plant expansion at the Water Treatment
Facility in 1999. Significant conservation was realized beginning in 2003. The resulting excess capacity
allowed for the City to sell 5 million gallons per day (MGD) of the estimated 20 MGD to a neighboring water
district for $12.5M.
3a. Council Finance Committee Materials
The updated and prioritized 10 year Capital Improvement Plans (CIP) were presented to the Council Finance
Committee in April and June of 2016. See attached Agenda Item Summaries (Attachments 4 and 5) from
those meetings and the relevant section of the Meeting Minutes.
The 10 year CIPs show what capital investments would be done in each year based on the prioritization of the
investment and the available resources for the capital project. The capital investment required over the next
decade is not the result of deferring infrastructure investment in the past but rather is the result of significant
increases in the expected capital investment over the coming decade compared to the previous decade in the
Water and Stormwater utilities.
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Below are a few tables from the CIPs which summarize the general categories of investment and the
requested dollars by year. Additional detail is available in the CIP documents that are included with
Attachment 4.
Light & Power CIP
Light & Power Fund Capital Expenditures
Type of Project 2017 2018 2019 2020 2021
Total for New Capacity $4,654,000 $3,628,000 $1,034,000 $1,770,000 $2,970,000
Total for Annexations $140,000 $3,015,000 $3,000,000 $3,000,000 $3,000,000
Total for Replacement Projects $3,555,000 $3,223,000 $3,662,000 $4,143,000 $3,941,000
Total for Operational Technology Projects $2,990,000 $1,930,000 $90,000 $90,000 $90,000
Grand total for all LPO Capital Projects $11,339,000 $11,796,000 $7,786,000 $9,003,000 $10,001,000
1-5 Year Light & Power Fund Capital Expenditures
Type of Project 2022 2023 2024 2025 2026
Total for New Capacity $8,050,000 $13,370,000 $3,303,139 $0 $0
Total for Annexations $3,150,000 $3,150,000 $0 $0 $0
Total for Replacement Projects $2,300,000 $2,356,000 $2,413,000 $2,346,000 $2,091,000
Total for Operational Technology Projects $90,000 $90,000 $90,000 $90,000 $90,000
Grand total for all LPO Capital Projects $12,940,000 $15,816,000 $5,807,000 $2,436,000 $2,181,000
6-10 Year Light & Power Fund Capital Expenditures
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Water CIP
Water Enterprise Fund Capital Spend
Division 2017 2018 2019 2020 2021
Water Production $4,665,000 $12,821,000 $3,174,000 $2,535,000 $1,000,000
Water Distribution $6,153,000 $3,810,000 $3,737,000 $5,683,000 $5,957,000
Water Resources $554,000 $558,000 $13,128,000 $14,418,000 $2,680,000
Environmental Services $1,350,000 $1,350,000 $50,000 $50,000 $50,000
Total $12,722,000 $18,539,000 $20,089,000 $22,686,000 $9,687,000
1-5 Year Water Fund Capital Needs
Division 2022 2023 2024 2025 2026
Water Production $16,772,000 $3,395,000 $14,031,000 $1,000,000 $1,000,000
Water Distribution $5,515,000 $6,511,000 $6,451,000 $6,451,000 $6,451,000
Water Resources $216,000 $222,000 $228,000 $237,000 $247,000
Environmental Services $50,000 $50,000 $50,000 $50,000 $50,000
Total $22,553,000 $10,178,000 $20,760,000 $7,738,000 $7,748,000
6-10 Year Water Fund Capital Needs
Wastewater CIP
Wastewater Fund 10-Year Funding Needs.
Division 2017 2018 2019 2020 2021
Water Reclamation $7,810,000 $10,880,000 $5,733,000 $3,540,000 $3,050,000
Wastewater Collection $2,050,000 $2,570,000 $3,202,000 $3,048,000 $2,907,000
Environmental Services $355,000 $30,000 $50,000 $50,000 $50,000
Total $10,215,000 $13,480,000 $8,985,000 $6,638,000 $6,007,000
1-5 Year Wastewater Fund Capital Needs
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Division 2022 2023 2024 2025 2026
Water Reclamation $3,050,000 $2,050,000 $2,050,000 $2,259,500 $5,362,000
Wastewater Collection $3,383,000 $3,276,000 $3,889,000 $4,123,000 $3,980,000
Environmental Services $50,000 $50,000 $50,000 $50,000 $50,000
Total $6,483,000 $5,376,000 $5,989,000 $6,432,500 $9,392,000
6-10 Year Wastewater Fund Capital Needs
Stormwater CIP
Stormwater 10-Year Capital Expenditures
Category 2017 2018 2019 2020 2021
Major Capital $ 5,750,000 $ 6,510,000 $ 25,500,000 $ 22,750,000 $ 24,050,000
Small Capital $ 1,400,000 $ 1,500,000 $ 1,600,000 $ 1,700,000 $ 1,800,000
Boxelder Basin Stormwater Authority $ 350,000 $ 350,000 $ 350,000 $ 350,000 $ 350,000
Stream Rehabilitation $ 350,000 $ 1,400,000 $ 800,000 $ 850,000 $ 900,000
Total $ 7,850,000 $ 9,760,000 $ 28,250,000 $ 25,650,000 $ 27,100,000
Average Annual Expenditure $ 15,409,000 $ 15,409,000 $ 15,409,000 $ 15,409,000 $ 15,409,000
1-5 Year Stormwater Fund Capital Needs
Category 2022 2023 2024 2025 2026
Major Capital $ 17,950,000 $ 6,250,000 $ 5,750,000 $ 3,750,000 $ 4,280,000
Small Capital $ 1,900,000 $ 2,000,000 $ 2,100,000 $ 2,200,000 $ 2,300,000
Boxelder Basin Stormwater Authority $ 350,000 $ 350,000 $ 350,000 $ 350,000 $ 350,000
Stream Rehabilitation $ 950,000 $ 1,000,000 $ 1,050,000 $ 1,100,000 $ 1,150,000
Total $ 21,150,000 $ 9,600,000 $ 9,250,000 $ 7,400,000 $ 8,080,000
Average Annual Expenditure $ 15,409,000 $ 15,409,000 $ 15,409,000 $ 15,409,000 $ 15,409,000
6-10 Year Stormwater Fund Capital Needs
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Ramifications of limiting rate increases to 3.0% in the Water Fund
Lowers annual revenue increase by $500K
Near term (2017-18) offers not funded or reduced 2017 2018
Offer 6.19 - Conservation Coordinator (unfunded) $70K
Offer 6.23 - Utility Inspector (unfunded) $85K
Offer 6.28 - Water Vulnerability Assessment (unfunded) $250K
Offer 6.26 - Underground Electric Supply (reduced) $95K
Offer 6.29 - Cathodic Protection (reduced) $1.0M
Longer term (2017-26) would reduce revenues by at least $10M and delay capital improvements
3b. What is the difference between limiting rate increases to 3% rather than 5%?
There were three variations to this question that were considered in the discussion on First Reading:
a. What happens if we limit the rate increases in 2017 and 2018 to 3% for Water and Stormwater?
b. What happens long term if we limit rate increases to 3% rather than 5%?
c. How was it determined that the rate ceiling should be 5% and not 3%?
a. What happens if we limit the rate increases in 2017 and 2018 to 3% for Water and Stormwater?
The immediate impact is to the 2017-2018 Budget. The tables below show what would not be funded if the
rate increases were lowered from the currently budgeted 5% to 3%.
Ramifications of limiting rate increase to 3.0% in the Stormwater Fund
Lowers annual revenue increase by $300K
Near term (2017-18) offers not funded 2017 2018
Offer 8.6 - Stream Rehabilitation Program (unfunded in 2017; reduced in 2018) $350K $300K
Longer term (2017-31) would reduce revenues by $4.5M
Alternative - Debt Issuance in 2017
Utilize proceeds to support capital improvements
Giving priority to stream restoration
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The long term impact of deferring rate increases is to limit the financial agility of the utility and to impose
obligations on the community in the future to make larger capital investments. Doing so for one or two years
only still allows for long term revenues and capital investments to be realized.
b. What happens long term if we limit rate increases to 3% rather than 5%?
In terms of where utility rates will be at in 10 years under each rate ceiling, the utility rates will be very close to
each other. This is because limiting the size of the rate increase leads to more rate increases being requested
to meet revenue requirements. This can be seen in the Water utility for example where the average annual
rate increase settles around 2.5% and the number of increases requested declines slightly from 8 in 10 years
to 6 in 10 years.
The rates overall also level off.
Thus, limiting annual rate increases to no more than 3% rather than 5% doesn’t necessarily result in lower long
term water rates. It does not result in higher water rates either. But what about the financial health of the
utility?
The debt coverage ratio is expected to be so much above the target of at least 2.0 that there is little difference
in this metric between 3% and 5% either. There is a slight difference in the amount of debt being issued
though.
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Looking at the annual operating revenue and the Available Reserves shows bigger trends and differences between
3% and 5%.
In general, limiting rate increases to a ceiling that is close to the long term rate of inflation limits the financial
agility of the utility to increase revenues when needed whether to meet a debt coverage ratio, near term capital
investment needs or operating income requirements. While a rule could be established around how to select
the rate ceiling it is immediately clear that for this utility anything less than 5% will make it difficult to maintain
positive operating income.
c. How was it determined that the rate ceiling should be 5% and not 3%?
This question is where there is a break from the mathematical rigor behind the long term financial model and
some judgement is necessary since a rate ceiling needs to be a long term ceiling that doesn’t change very
frequently. The above discussion of the water utility in answering version (b) of this question outlines some of
the considerations when considering the rate ceiling.
The determination of what the rate ceiling should be needs to balance the financial position of the utility with
the impacts to the customers. Limiting the rate ceiling to 3% means the rate increase frequency is 0.8 per year
and average magnitude of 2.2%. This compares to a rate increase frequency of 0.6 per year and average
magnitude of 2.5%. Looking across the utilities a 1-3% the rate ceiling would require annual adjustments in
some of the utilities just to keep up with the inflation of operating and construction costs. At 3-5% the curves
above start to change. Above 5% most of the curves above show that the financial health of the utility begins
to stabilize.
At both the April and June Council Finance Committee meetings, the assumption that rate increases would be
limited to no more than 5% was presented. While the 5% was proposed as a target, adopting a formal policy
on this would not be advised as it would put a financial constraint on each utility that is common and may be
viewed detrimentally by others assessing the financial health and agility of each utility.
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ATTACHMENTS
1. First Reading Agenda Item Summary, November 1, 2016 (w/o attachments) (PDF)
2. Historical Utilities Rate Increases Memo, November 10, 2016 (DOCX)
3. Westminster Value of Water Conservation (PDF)
4. Council Finance Committee, April 18, 2016 - Capital Improvement Plans (PDF)
5. Council Finance Committee, June 20, 2016 - Utilities Strategic Financial Plan (PDF)
6. Ordinance No. 122, 2016-Electric Rates (Option 2-not adopted on First Reading) (PDF)
7. Ordinance No. 123, 2016-Water Rates (Option 1-not adopted on First Reading) (PDF)
8. Ordinance No. 125, 2016-Stormwater Rates (Option 2-not adopted on First Reading) (PDF)
Agenda Item 11
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AGENDA ITEM SUMMARY November 1, 2016
City Council
STAFF
Lance Smith, Strategic Financial Planning Manager
SUBJECT
Items Relating to 2017 Utility Rate Ordinances.
EXECUTIVE SUMMARY
A. First Reading of Ordinance No. 122, 2016, Amending Chapter 26 of the Code of the City of Fort Collins to
Revise Electric Rates, Fees and Charges. (Option 1 or Option 2)
B. First Reading of Ordinance No. 123, 2016, Amending chapter 26 of the Code of the City of Fort Collins to
Revise Water Rates, Fees and Charges. (Option 1 or Option 2)
C. First Reading of Ordinance No. 124, 2016, Amending Chapter 26 of the Code of the City of Fort Collins to
Revise Wastewater Rates, Fees and Charges.
D. First Reading of Ordinance No. 125, 2016, Amending Chapter 26 of the Code of the City of Fort Collins to
Revise Stormwater Rates, Fees and Charges. (Option 1 or Option 2)
The purpose of this item is for Council to consider adopting rate changes for electric, water, wastewater and
stormwater monthly charges beginning in January 2017. It is unusual to have all four utilities request a rate
increase in a single year. It may also seem counterintuitive that the utility budgets are decreasing in 2017 yet
rate increases are being proposed. However, the extensive capital improvement planning and long term
financial planning processes ahead of this Budgeting For Outcomes cycle have identified the need for rate
increases in each utility in 2017 despite the budget reductions.
The proposed rate increases for 2017 and 2018, as well as the primary driver behind the requested increases,
are outlined in the table below.
ATTACHMENT 1
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STAFF RECOMMENDATION
Staff recommends adoption of the rate increases as included in the 2017 Budget being considered at this
meeting.
Staff recommends adoption of the Ordinances on First Reading. Staff recommends adoption of the Ordinance
allocating the whole electric rate increase to the fixed or base monthly service charge (labeled Option 2 below)
as well as the adoption of the Ordinances which include a 5% increase for water (Option 2) and stormwater
(Option 1) monthly charges.
BACKGROUND / DISCUSSION
2017-18 Budgets for Utility Funds
There is a direct connection between utility rates and the biennial budget. Monthly service charges need to be
adequate to meet operating expenses for each utility and to provide additional revenues to support ongoing
infrastructure renewal and improvements that may be necessary in the next budget cycle. However, there are
also long-term planning considerations which may drive the need for rate adjustments. That is the situation
this year.
The CMRB 2017-18 includes significant reductions in the overall Utilities budget. These reductions are not the
result of reducing services but rather are driven by a concerted effort to build up each Fund’s budget from the
bottom up as a way of reducing the annual underspend that is inherent in a municipal utility budget. The
resulting budgets are expected to still be sufficient for each utility however, reducing the budgets increases the
likelihood that an unexpected event may require staff to request an off-cycle appropriation from Council. The
table below summarizes the 2017 budgets relative to the 2016 adjusted budgets.
Proposed Revenue Adjustments
Utility Service 2017 2018 Primary Driver
Electric 3.45% 1.80% Insufficient Operating Income
Water 5.00% 5.00%
Inadequate Available Reserves to support
10 year Capital Improvement Plan
Wastewater 3.00% 3.00% Revenue shortfalls in 2015 and 2016
Stormwater 5.00% 0.00%
Inadequate Available Reserves to support
15 year build-out of infrastructure
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Attachment 2 provides a one page summary of each Utility Fund’s 2017-18 budgets by Offer as in the City
Manager’s Recommended Budget. These summaries also show the use of Available Reserves and the
expected Available Reserve balances at the end of 2018. For Water and Stormwater there are two one page
summaries based on feedback that consideration should be given to limiting those rate increases to 3.0%
rather than 5.0%.
2016 Capital Improvement Plans and Long-term Financial Planning
The prioritized 2016 Capital Improvement Plan (CIP) for each utility was presented to the Council Finance
Committee (CFC) in April 2016. At that time it was recognized that it is not possible to meet the capital needs
of each utility necessary to maintain the current levels of service being provided with existing rates and use of
Available Reserves. As discussed in Attachment 3 this is not the result of deferring infrastructure investment
in the past but rather is the result of significant increases in the expected capital investment over the coming
decade compared to the previous decade.
After further analysis staff returned to the CFC in June 2016 with a path forward based on a 10 year financial
model for each utility to meet the long term infrastructure renewal and additional capacity needs. The path
forward, or Strategic Financial Plan (SFP), was unique to each utility but each was based on the central tenets
presented at the April CFC meeting. Those tenets incorporated into the financial modeling were:
1. Meet minimum Reserve requirements
2. Maintain current credit ratings for each Enterprise Fund and the City
3. Limit rate increases to no more than 5% annually
4. Adjust rates when:
a. Previous 3 years averaged negative operating income
b. Debt coverage ratio is projected to drop below 2.0 in the next year
c. Available Reserves are insufficient for near term necessary capital investment
d. Any purchased power cost increase is expected from Platte River
5. Issue debt when:
a. Capital expenses are forecasted to exceed Available Reserves over the next 5 years
b. Issue debt no more frequently than once every 3 years
Budget Change Budget Change
2016-2017 2016-2017
ELECTRIC $143.8 $141.2 ($2.6) -1.9%
Reduced O&M 10%; Increased
capital based on CIP
WATER * $46.6 $34.8 ($11.8) -25.4%
Reduced O&M 2.2%; Reduced
capital from $20M to $9M
WASTEWATER $28.5 $25.5 ($3.0) -10.4%
Reduced O&M 2.1%; Reduced
capital from $10M to $7M
STORMWATER ** $16.7 $18.7 $2.0 12.2%
O&M increased 4.0%; Increased
capital from $5M to $7M
Customer Service &
Administration
$18.1 $17.2 ($0.9) -5.2%
Reduced Customer Connections
3.1% and Administration 7.8%
Total Utilities $253.7 $237.4 ($16.3) -6.4%
Every manager’s budget was
reviewed at the line item level
and adjusted based on 2015
actual spend
* Assumes 5% rate increase for Water
** Assumes 5% rate increase for Stormwater
UTILITY
2017 Budget
$M
Comments
2016 Budget
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Tenet 4 provides an objective, quantitative method that could be utilized for future rate adjustments. It would
determine when and why rate adjustments are necessary in a consistent manner and direct attention toward
the root drivers of any such adjustment.
The resulting financial models for each utility suggest that gradual, modest rate increases and some debt
issuances will allow each utility to meet the capital investments identified over the coming 10-15 planning
horizon. Below is a brief overview of this effort for each utility taken from Attachment 3.
Light & Power Fund’s SFP
For Light & Power, the SFP presented to the CFC in June 2016 required no additional debt issuances. The
current outstanding debt will be retired in 2021. Rate increases will be necessary as Platte River moves
forward with meeting the Clean Power Plan and the distribution system is renewed. The 10 year rate forecast
for the electric utility is:
Included in the above rate forecast is 2.5% annually for purchased power increases. Not included in the above
forecast is any additional rate adjustment that may be necessary to achieve the Road to 2020 objectives
although it is not anticipated that a full 1.5% will be necessary annually for the distribution system.
Water Fund’s SFP
For Water the 10-year prioritized CIP that was presented to the Water Board and the CFC in April 2016
projects that necessary capital improvements over the coming decade will be at a rate that is twice what it has
been over the past decade. It is also front heavy in capital needs. The SFP outlined a path forward which
required leveling the capital investment over the coming 10 years to the extent possible and allows for modest
rate adjustments and debt issuances. The need and schedule for debt issuances will be discussed with the
CFC in December 2016. The 10 year rate forecast and anticipated debt issuances for the water utility are:
Wastewater Fund’s SFP
For Wastewater no additional debt is anticipated to be necessary over the next decade in the SFP. However,
rate increases will be necessary to address the ongoing operating revenue shortfall. The 10 year rate forecast
for the wastewater utility is:
2017 2018 2019 2020 2021 2022 2023 2024 2025 2026
Rate Increase 2-5% 2-4% 2-4% 2-4% 2-4% 2-4% 2-4% 2-4% 2-4% 2-4%
* Rate increases may change depending on what PRPA needs each year.
2017 2018 2019 2020 2021 2022 2023 2024 2025 2026
Rate Increase 0-5% 1-5% 1-3% 1-3% 3-5% 3-5% 3-5% 3-5% 3-5% 3-5%
Debt Issuance $30M $20-30M $3-5M
* $160M of capital work is expected to be needed between 2017 and 2026 NOT including Halligan
2017 2018 2019 2020 2021 2022 2023 2024 2025 2026
Rate Increase 1-3% 1-3% 1-3% 1-3% 1-3% 0-3% 0-3% 0-3% 0-3% 0-3%
* $80M of capital work is expected to be needed between 2017 and 2026.
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Stormwater Fund’s SFP
For Stormwater in order to complete the initial build-out of all the major outfalls significant capital investment
will be needed. The original 10 year CIP would have required issuing too much debt at once so the plan was
stretched out over 15 years. This will address the majority of existing deficiencies. Some rate increases will
be necessary but the capital investment will mainly be funded through debt. The 10 year rate forecast and
anticipated debt issuances for the stormwater utility are:
2017 Proposed Rate Increases
Light & Power
A 3.45% rate increase is being proposed for the Light & Power Fund in 2017. This proposed rate adjustment
is being driven by the need to increase operating income for the distribution Enterprise Fund and an increase
in the purchased power costs from Platte River. The proposed retail rate increase will become effective on
January 1, 2017 and will vary by rate class. The proposed wholesale increase from Platte River will also be
effective in January 1, 2017, but not officially approved by its Board until late October. Both Platte River and
the City have rates that vary by season. Summer rates are effective for June, July and August with the non-
summer rates in effect for the remaining nine months of the year.
The increase in Platte River’s 2017 wholesale rate is currently projected to be 3.0%. Within this increase,
PRPA is proposing to modify the individual components for energy and demand for the summer and winter
seasons, as shown in the table below.
Charge 2016 Approved
Tariff
2017 Proposed
Budget
% Change
Demand – Summer (per kW) $11.33 $11.33 0%
Demand – Winter (per kW) $7.91 $8.64 9%
Energy – Summer (per kWh) $0.04121 $0.04200 2%
Energy – Winter (per kWh) $0.03954 $0.04028 2%
At the wholesale level, the energy charge will increase 1.9% for both seasons. The demand charge for the
summer season will remain flat, with no increase, while the winter demand charge will increase by 9.2%.
For Fort Collins Utilities customers, the above rates will be a pass through and equal a 1.9% increase for
energy and a 5.7% increase for demand (blended on an annual basis), as calculated on total billed mix for
2015.
The overall wholesale increase of 3.0% will equate to an approximate increase of 2.2% at the retail level. In
addition, Fort Collins Utilities is proposing a 1.25% increase for the distribution system, for an overall average
increase of 3.45%.
There are three drivers behind the requested increase for the distribution system:
1. The Light & Power Fund intentionally has been drawing down reserves through negative operating
income. As an Enterprise Fund, it is expected to generate positive operating income. Now that the
reserves have been drawn down a rate increase is necessary to generate sufficient operating
revenues.
2017 2018 2019 2020 2021 2022 2023 2024 2025 2026
Rate Increase 0-3% 0-3% 0-3% 0-3% 0-3% 0-3% 0-3% 0-3% 0-3% 0-3%
Debt Issuance $20-25M $20-25M $5-10M
*$156M of capital work is expected to be needed between 2017 and 2031.
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2. Several ongoing operating expenses were approved in 2015 and 2016 for the Road to 2020 efforts.
3. The 2016 CIP shows capital needed over the next decade is on par with what was spent in the last
decade at $8-9M annually. However, there is no expectation of another large grant (like the $16M
Smart Grid Investment Grant) so revenues will have to increase to meet these needs.
The cost of service model is updated every two years, and was last updated in 2014 for 2015. Staff updated
the cost of service model again in 2016 for 2017. The rate class percentage adjustments are shown in the
graph below. The horizontal line represents the average retail increase of 3.45%. Variations by rate class are
due to multiple factors, including changes in total consumption (either up or down), changes in customer
counts, changes in load factors, and dependent on specific costs and allocations to each rate class. As the
graphs shows, no one particular rate class varies, either up or down, by more than one percent from the
average of 3.45% increase.
The 4.2% increase to the residential rate class could be applied to both fixed and variable charges or to just
one or the other. All rates below are without the 6% payment in lieu of tax. Staff is presenting two options for
Council’s consideration on how to apply the 4.2% rate increase to residential customers:
Option 1 - Increase the monthly fixed charge from $5.07 to $5.79 as the cost of service model shows is
necessary. The distribution facilities charge would also increase from $0.0238/kWh to $0.0256/kWh. This
allows the clear delineation of what is in the fixed charge to be maintained.
Option 2 - Leave the distribution facilities charge unchanged and put the entire rate increase (excluding
wholesale increases) in the monthly fixed charge. This would increase the fixed charge from $5.07 to
$6.94. Doing this would stabilize revenues by allowing more of the fixed costs to be included in the fixed
charge. Staff is recommending this option. See Attachment 4 for the context of the CFC discussion on
fixed charges in September 2016.
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In addition to the changes in City Code related to the rate increase there is also a change to recognize an
income qualified community solar project. Light & Power is installing a solar array on the roof of the City-
owned building at 518 Loomis Street in October 2016 to benefit low-income customers. Utilities will rely on the
Low Income Energy Assistance Program’s (LEAP’s) qualification process to verify household income and
select participants. The monthly production of the solar array will be split equally between participating
households. Much like the existing community solar garden array, a monthly bill credit will be applied to those
households. It is expected to benefit around 20 income-qualified households.
Water
The 2016 operating revenues are expected to be $300-500K short of the budgeted projection. This updated
forecast negatively impacts the debt capacity of this Enterprise Fund. Low Available Reserves in this Fund
and the need to maintain the debt capacity for a near term debt issuance are driving the need for a 5% rate
increase in 2017 and 2018. The cost of service study for the Water Fund was updated in 2015. Since all rate
class adjustments needed from the results of that study were made in 2016, the proposed increase for 2017
will be the same for all rate classes.
After looking at the current Available Reserves and the near term capital needs outlined in the CIP ($33M in
2017-18 alone), the amount of capital work in the CMRB 2017-18 is $22M, or $11M less than the CIP. This is
because the current rates cannot support the 5 year capital needs of this Enterprise Fund. As discussed
above, there is also a need to issue debt in the near term.
Staff is presenting two options for Council’s consideration on the magnitude of the proposed rate increase for
2017:
Option 1 - Increases monthly charges by 5.0% in 2017 for all water customers. A 5% rate increase will
increase the debt capacity of this Fund by $8-15M, which along with a portion of the debt service that
will be retired in 2018, will allow for the issuance of revenue bonds in 2018. By increasing the rates in
2017 it will be clear to the bond rating agencies that net pledged revenues will be sufficient to pay all
future debt obligations.
Option 2 – Increases monthly charges by 3.0% in 2017 for all water customers. A 3% rate increase in
the Water Fund would require some Offers in the CMRB 2017-18 to be unfunded or funded at a lesser
amount in 2017 and 2018. It would also lessen the increase of the debt capacity of this Fund and
reduce 2017 revenues by $520,000.
2016
Option 1Option 2
Component Current COS Model No Change to kWh
Fixed Charge $ 5.07 $ 5.79 $ 6.94
Distribution kWh $ 0.0238 $ 0.0256 $ 0.0238
2017 Options
Agenda Item 11
Item # 11 Page 8
Wastewater
There is a 3.0% overall rate increase proposed for the Wastewater Utility in 2017. Operating revenues for the
Wastewater utility continue to be below budget. The 3.0% increases in both 2017 and 2018 in the CMRB
2017-18 are expected to adequately address this revenue shortfall.
The cost of service study for the Wastewater fund was updated in 2015. Since all rate class adjustments
needed from the results of that study were made in 2016, the 3% increase for 2017 will be the same for all rate
classes. The main driver for the 2017 increase is related to the ongoing revenue shortfall that has continued in
2016. This revenue shortfall impacts the Enterprise Fund’s ability to financially support the 10-year CIP.
These modest rate adjustments in both 2017 and 2018 are expected to address this continued revenue
shortfall and put this Fund on a path to provide sufficient Available Reserves to complete the 10-year CIP
without the need to issue new debt. This Fund is also projected to have sufficient Available Reserves to
implement anticipated nutrient removal requirements just beyond the 10-year horizon without needing to issue
addition debt.
Stormwater
A 5% rate increase is being proposed for the Stormwater Fund in the CMRB 2017-18. Operating revenues are
higher than budgeted due to growth and annexations in 2016. Together with the proposed 5% rate increase
these additional revenues will increase the debt capacity of the Stormwater Fund by $12-25M allowing the
initial build out of much of the stormwater infrastructure to be on a 15-year completion schedule beginning in
2017.
Option 1 - Increases monthly charges by 5.0% in 2017 for all stormwater customers. A 5% rate
increase will increase the debt capacity of this Fund by $12-25M, which along with a portion of the
debt service that will be retired in 2018, will allow for the issuance of revenue bonds in 2017. By
increasing the rates in 2017 it will be clear to the bond rating agencies that net pledged revenues will
be sufficient to pay all future debt obligations.
Option 2 – Increases monthly charges by 3.0% in 2017 for all stormwater customers. A 3% rate
increase in the Stormwater Fund would reduce some stream rehabilitation Offers in the CMRB 2017-
18. It would also lessen the increase of the debt capacity of this Fund.
Ramifications of limiting rate increases to 3.0% in the Water Fund
Lowers annual revenue increase by $500K
Near term (2017-18) offers not funded or reduced 2017 2018
Offer 6.19 - Conservation Coordinator (unfunded) $70K
Offer 6.23 - Utility Inspector (unfunded) $85K
Offer 6.28 - Water Vulnerability Assessment (unfunded) $250K
Offer 6.26 - Underground Electric Supply (reduced) $95K
Offer 6.29 - Cathodic Protection (reduced) $1.0M
Longer term (2017-26) would reduce revenues by at least $10M and delay capital improvements
Agenda Item 11
Item # 11 Page 9
Plant Investment Fees
No changes are proposed for any of the utility Plant Investment Fees (PIFs) in 2017 at this time. A review of
the Electric Capacity Fees (ECF) will be presented to the Council Finance Committee at the December 19,
2016 meeting and then to the Council at the January 10, 2017 Work Session. Depending on Council direction,
the ECF may be adjusted later in 2017. The water, wastewater and stormwater plant investment fees will be
reviewed as part of the biannual cost of service studies in 2017.
CITY FINANCIAL IMPACTS
Impact to Enterprise Funds
The proposed rate increases are necessary to support both the near term budget and the long term capital
improvement plans necessary to maintain the current levels of service being provided to our community.
Adoption of these Ordinances will improve the financial resiliency of each utility.
Summary Utility Bill Comparisons
A typical residential customer, based on average use for each utility service, would see an increase of $6.52
per month on their total utility bill, if they receive all four utility services through the City. This represents a
4.00% increase in monthly utility costs.
Comparing rates between communities provides one point of contrast but it should be done carefully. Rates
are a function of the utility infrastructure age, management and operation. Rates can be depressed by
deferring capital improvements, for example. It is not possible to fully understand all of the drivers behind what
other communities may consider in their rate decisions. Nevertheless, below are a few comparisons of the
proposed 2017 utility rates for several neighboring communities. The first table shows the estimated bill for a
typical residential customer. Because of the large increases being proposed in some communities the gap
shown in the total utility bill for the other communities with all 4 services is shrinking in 2017.
Ramifications of limiting rate increase to 3.0% in the Stormwater Fund
Lowers annual revenue increase by $300K
Near term (2017-18) offers not funded 2017 2018
Offer 8.6 - Stream Rehabilitation Program (unfunded in 2017; reduced in 2018) $350K $300K
Longer term (2017-31) would reduce revenues by $4.5M
Alternative - Debt Issuance in 2017
Utilize proceeds to support capital improvements
Giving priority to stream restoration
ELECTRIC WATER WASTEWATER STORMWATER TOTAL
Current 2016 $68.21 $43.57 $35.07 $14.26 $161.11
Proposed 2017 $71.07 $45.75 $36.12 $14.97 $167.91
$ Increase $2.86 $2.18 $1.05 $0.71 $6.80
% Increase 4.2% 5.0% 3.0% 5.0% 4.2%
Agenda Item 11
Item # 11 Page 10
Considering all customers the absolute percentage increases tend to be less modest than in Fort Collins:
BOARD / COMMISSION RECOMMENDATION
The electric rate increase was presented to the Energy Board at its October 6, 2016 Regular Meeting. The
Energy Board supported the 3.45% rate increase and recommends doing so by putting the entire increase into
the fixed charge. The motion carried unanimously. Please see the attached draft meeting minutes
(Attachment 1).
The water, wastewater and stormwater rate increases were presented to the Water Board at its October 20,
2016 Regular Meeting. The Water Board supported the 5% increase (Option 1 above) for the Water Fund and
the 3% increase to the Wastewater Fund unanimously. At the time the Water Board meeting was scheduled
only a 3% rate increase was presented to the board for consideration. The Water Board also supported the
3% increase in Stormwater by a 9-1 vote. Please see the attached draft meeting minutes (Attachment 5).
PUBLIC OUTREACH
Notice of the proposed electric rate increase was published in the Coloradoan, and a mailing was sent to all
electric customers residing outside of the city limits in accordance with state requirements.
Staff plans to conduct outreach to all customers following the adoption of the Ordinances through mailings,
face-to-face meetings and social media.
ELECTRIC WATER WASTEWATER STORMWATER TOTAL
Loveland $71.37 $37.06 $28.23 $13.68 $150.34
Longmont $65.78 $38.08 $34.64 $13.05 $151.55
Boulder $79.67 $38.71 $30.53 $14.54 $163.45
Greeley $79.67 $52.89 $20.62 $6.97 $160.15
Ft Collins $71.07 $45.75 $36.12 $14.97 $167.91
Colorado Springs $88.28 $82.49 $31.27 N/A $202.04
ELECTRIC WATER WASTEWATER STORMWATER TOTAL
Loveland 6.50% 9.00% 11.00% 9.60% 8.20%
Longmont 4.00% 21.00% 3.00% 0.00% 7.20%
Boulder 0.00% 8.00% 5.00% 8.00% 3.40%
Greeley 0.00% 3.00% 0.00% 8.00% 1.30%
Ft Collins 3.45% 5.00% 3.00% 5.00% 3.90%
Colorado Springs 3.30% 6.00% 0.00% N/A 3.80%
Agenda Item 11
Item # 11 Page 11
ATTACHMENTS
1. Energy Board minutes, October 6, 2016 (draft) (PDF)
2. All Utilities Master Summary (PDF)
3. Council Finance Committee Agenda Item Summary - Utilities Strategic Financial Plan, June 20, 2016
(PDF)
4. Council Finance Committee Agenda Item Summary-Residential Electric Rate Structure, September 19,
2016 (PDF)
5. Water Board minutes, October 20, 2016 (draft) (PDF)
6. Powerpoint presentation (PDF)
Page 1 of 6
Utilities
electric · stormwater · wastewater · water
700 Wood Street
PO Box 580
Fort Collins, CO 80522
970.221.6700
970.221.6619 – fax
970.224.6003 – TDD
utilities@fcgov.com
fcgov.com/utilities
M E M O R A N D U M
DATE: November 10, 2016
TO: Mayor and City Councilmembers
FROM: Lance Smith, Utilities Strategic Finance Director
THRU: Darin Atteberry, City Manager
Kevin R. Gertig, Utilities Executive Director
RE: 20 Year Historical Utility Rate Adjustments
The First Reading of the utility rate Ordinances for 2017 was on November 1, 2016. This memo
is in response to a request by Council during the discussion of these Ordinances on rate
adjustments over the past 20 years. Below are comparisons of each utility’s rates over the most
recent 20 years (1996-2015) to the Greeley-Boulder CPI, Larimer County Personal Income and
Fort Collins Housing.
Relative to Boulder-Greeley CPI
Page 2 of 6
Relative to Larimer County Personal Income
Relative to Fort Collins Housing
By Utility
Page 3 of 6
Page 4 of 6
Page 5 of 6
Page 6 of 6
Conservation Limits Rate
Increases for a Colorado Utility
Demand Reductions Over 30 Years
Have Dramatically Reduced Capital Costs
NOVEMBER, 2013
ATTACHMENT 3
Authors
Stuart Feinglas
Water Resources Analyst
City of Westminster
Christine Gray
Management Analyst
City of Westminster
Peter Mayer, P.E.
Principal
Water Demand Management
Alliance for Water Efficiency | November, 2013
| 1
Why are my rates going up again?
“Why do you ask me to conserve and then raise my rates?” asked a concerned
citizen at a public meeting in Westminster, Colorado in 2011.
“Very good question,” pondered Westminster Utilities’ staff as they struggled with
only limited success for a compelling answer. They knew water conservation has
had a profound impact on the city by reducing demand, the amount of additional
water needed to purchase and eliminating the need for expansion of facilities,
but they didn’t have a good way to quantify the impacts and respond to the
citizen’s question.
Similar tough questions have been posed to water utilities across the country as
water and wastewater rates have increased faster than the Consumer Price Index
(CPI) over the past 15 years, (Beecher 2013), (Craley and Noyes 2013). Managing
the public response to and understanding of rate increases has taken on
increasing significance in recent years as utilities grapple with the double edged
sword of rising infrastructure costs and decreasing demands (Goetz M. 2013).
Rather than leaving the question of customer conservation and rates hanging
without a satisfactory response, the Westminster staff decided to do some research
to try and come up with some answers using data from their own system. The
timing of the question was significant as the City is working towards completing
a series of identified projects designed to meet the City’s needs at a projected
buildout date of 2050 (using current and projected demands which include
conservation).
To examine the impact of conservation on rates, the City looked at marginal
costs due to the buildout requirements by removing conservation from the
equation. The results of the City’s research were startling: Reduced water use in
Westminster since 1980 has resulted in significant savings in both water resource
and infrastructure costs, saving residents and businesses 80% in tap fees and 91%
in rates compared to what they would have been without conservation.
The City’s research on water demands and rates since 1980 provided a useful
response to the citizen’s question and revealed previously unexplored and under-
appreciated benefits of long-term water conservation in reducing rate increases.
Water rates in Westminster are much lower today than they would have been in
the absence of demand reductions from conservation. Here’s how the City was
able to reach this important conclusion.
Conservation Limits Rate Increases for a Colorado Utility
2 |
Change in Water Use
To explore the impacts of demand management on water rates
and tap fees, Westminster staff examined water demand records,
water rates, tap fees1, and capital project costs from 1980 through
2010 with the following question in mind: “What would our
water rates and tap fees be today if per customer water demands
remained unchanged since 1980?”. 1980 was chosen because it
predated City related conservation programs and two levels of
plumbing code related changes.
The first step was to examine water use patterns. To do this,
Westminster staff examined water use patterns from 1980 – 2010
by taking total demand (all customer classes) and dividing by
the best estimate of the service area population for each year.
Westminster has a reclaimed water system that reuses treated
wastewater for irrigation thus lowering the City’s impact on water
resources. To be conservative, reclaimed water was assumed to be a conservation measure.
This consumption was added back into potable water use to reflect the full use of water
without conservation. As shown in Figure 1 average gpcd, based on total City water use,
was 21% higher 30 years ago, starting at 180 gpcd in 1980 and ending at 149 gpcd in 2010.
Westminster attributes these changes in demand to three primary management factors:
1. Utility sponsored water conservation programs
2. The City’s inclining block and seasonal rate water billing structure
3. National plumbing codes implemented as part of the Energy Policy Act
of 1992 (EP Act)
1 Tap fees, also called connection fees or development fees, are the costs paid by new customers to join the
water system.
Alliance for Water Efficiency | November, 2013
| 3
100
120
140
160
180
200
1980 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010
Per Capita Use (Gallons Per Day)
Total Water Use Per Capita Since 1980
Figure 1: Average gpcd in Westminster, based on total water use 1980 – 2010
New Supply Requirements and Cost
Once the changes in water demand were quantified, the Westminster staff were able
to estimate what water use in 2010 would have been without the enactment of water
conservation programs and policies. Through this analysis it was concluded that if per
capita water use had not decreased by 21%, Westminster would have been required to
secure an additional 7,295 acre-feet (AF) of additional water supply order to meet the
customer demand while satisfying the City’s reliability requirements.
New water supply in Colorado’s Front Range does not come cheap. Current market
costs for new water supply average $30,000 per acre-foot on Colorado’s Front Range.
Westminster pays close attention to the cost of new supply as it builds these costs into
the tap fees of new customers so that the City can fully recover the expense of serving
new customers without burdening existing customers with the cost of growth. The staff
also concluded that had conservation from 1980 – 2010 not occurred, the City would
have been competing with other water providers in the region to acquire more raw water,
further tightening the market and making new water supply even more expensive. At this
average price, the estimated cost of obtaining and delivering the required additional 7,295
AF of water would have required a capital investment of $218,850,000. With this simple
analysis alone, the cost savings associated with reduced water use became obvious, but
staff realized this was only part of the story.
If per capita water use
had not decreased by
21%, Westminster would
have been required to
secure an additional
7,295 acre-feet (AF) of
additional water supply
order to meet the
customer demand.
Conservation Limits Rate Increases for a Colorado Utility
4 |
Additional Peak Demands and
Infrastructure Costs
Peak demand in 2010 would also have been considerably higher had conservation not
been implemented in Westminster over the past 30 years. The City has found that water
conservation programs have altered irrigation patterns thus reducing the system’s peak day
factor. In 1980 the peak to average day factor in Westminster was 3.0, but by 2010 changes in
irrigation practices and reduced water demand cut the peak factor to 2.1 — a 30% reduction.
If 1980 demand levels had been perpetuated along with the 1980 peaking factor of 3,
then the City’s peak requirement at buildout was estimated to be 52 MGD higher than the
current planned maximum capacity. This level of peak demand would require the City to
add an additional 52 MGD of treatment capacity at an estimated finished and installed
cost of $2,500,000 per MGD2. Developing the additional water treatment infrastructure
to meet these higher demands would have required a capital investment by the City of
approximately $130,000,000.
2 Based on recent projects and engineering estimates
0.0
0.5
1.0
1.5
2.0
2.5
3.0
3.5
0
5
10
15
20
25
30
35
40
45
50
1982
1984
1986
1988
1990
1992
1994
1996
1998
2000
2002
2004
2006
2008
2010
Peaking Factor
Gallons (in millions)
Potable Water Production
Peak Day, Daily Average, Peaking Factor
Peak Day Daily Average Peaking Factor Linear (Peaking Factor )
Alliance for Water Efficiency | November, 2013
| 5
Additional Wastewater Treatment
Infrastructure Costs
If conservation were not taken and water demands had stayed at 1980 levels, staff
determined that Westminster would have needed to add an additional 4 MGD of wastewater
treatment capacity to their system. Adding wastewater treatment capacity costs the City
an estimated $5,000,000 per MGD3. Thus the additional 4 MGD of wastewater would have
required a capital investment by the City of approximately $20,000,000.
Total Estimated Costs of Increased Demand
All estimated costs associated with the hypothetical increased demand were assembled into
a single table and then the City added in the costs of debt financing charges which would
certainly have been part of these capital construction projects, had they been implemented.
As shown in Table 1, had the citizens of Westminster not reduced their water use, the
estimated total cost to the City of the increased demand came to $591,850,000 – more than
half a billion dollars.
Table 1: Estimated new infrastructure costs of increased demand
Additional water treatment capacity 52 MGD total ($2,500,000/MG) $130,000,000
Additional wastewater treatment
capacity 4 MGD total ($5,000,000/MG) $20,000,000
Additional water resources 7,295 AF total ($30,000/AF) $218,850,000
Interest (on debt funding for
all projects)* $223,000,000
Total Costs $591,850,000
* For the purposes of this analysis it is assumed that debt would have been issued, and the resulting debt service would have been paid
through rates. Those costs were included in the impacts to rates.
3 Based on recent projects and engineering estimates
Conservation Limits Rate Increases for a Colorado Utility
6 |
Next the staff examined the increases in operating costs that the City estimates it would
have incurred to handle the increased demand and associated additional infrastructure.
While no additional staff personnel were assumed to be necessary, it was assumed that
operating costs (power, chemicals, and other annual costs related to water and wastewater
treatment, distribution and collection) would increase proportionally to the demand
increases as shown in Table 2. From this analysis, it was estimated that Westminster would
have incurred an additional $1,238,000 per year on average in operating costs associated
with the additional demand.
Table 2: Estimated additional operating costs of new demand*
Additional annual operating cost of water
treatment facilities 21% increase $480,400
Additional annual operating cost of wastewater
treatment facilities 20% increase $757,600
Total estimated additional operating costs $1,238,000 per year
*No additional staff personnel were added
Impact to Water and Wastewater Rates
and Tap Fees
Once the cost estimates were completed, the question of how to recover the additional
costs through rates and fees was examined. Westminster Utilities has just two sources
of revenue that it must use to pay for all costs associated with running the water and
wastewater systems: (1) Water and wastewater rates; and (2) Tap fees. In theory, water
and wastewater rates are set by the City so that the revenue generated covers operations
and maintenance of the system as well as some of the repair and replacement costs, and
debt service. Tap fees are set to cover the costs of buying into the existing system based
on current value plus any new infrastructure (capital projects), and water resources
required by growth.
In practice, existing customers build the City’s water and wastewater systems before new
customers arrive so that growth can occur. Infrastructure must be planned for future
demands and not constructed as needed. When new customers connect and pay their tap
fees, current customers are reimbursed for their investment in the City’s existing systems.
Those funds pay for capital improvement projects including repair and replacement, thus
reducing the costs to existing customers. Therefore, both rates and tap fees are impacted by
the same projects.
Alliance for Water Efficiency | November, 2013
| 7
Working from this basic division of costs between rates and tap fees, Westminster
developed an estimate of what 2012 water and wastewater rates and tap fees for single-
family customers would need to be to cover the additional costs incurred as a result of the
hypothetical additional supply requirements. In 2012, the average single-family customer
in Westminster paid a total of $410 for water and $245 for wastewater service. To cover the
single-family sector’s share of the additional annual costs associated with the increased
demand considered in this analysis, the average single-family customer would have to pay
an additional $553 per year for water service and $43 per year for wastewater service. The
weighted average of these additional costs means that the average single-family customer
would pay combined water and wastewater rates that are 91% higher than they are today
if 1980-level water demands were perpetuated over the past 30 years. These results are
shown in Table 3.
Table 3: New single-family rates and fees required to pay for additional demand
Total Avg. Per Customer
Charges in 2012
Additional Charges
Required to Cover
New Costs
New 2012 Annual SF
Water/Sewer Bill
% Increase in Charges from
Additional Demands
Water $410 $553 $963 135%
Sewer $245 $43 $288 17%
Total $655 $596 $1,251 91%
A similar analysis was conducted to examine the impact of increased demands on tap
fees for new customers in Westminster. In 2012 the average tap fee for a new customer
(residential and non-residential combined) was $21,229, of which 77% was for water and
23% was for wastewater components. The combined cost of new infrastructure, new water
resources, and repair and replacement associated with the increased demand modeled in
this analysis would require an 80% increase in the average tap fee, up to $38,181 as shown in
Table 4.
Table 4: New tap fees required to pay for additional demand
Avg. Per Customer
Tap Fee in 2012
Additional Tap Fee
Charges Required to
Cover New Costs
New 2012 Avg.
Tap Fee
% Increase in Charges from
Additional Demands
Water $16,325 $16,086 $32,411 99%
Sewer $4,904 $866 $5,770 18%
Total $21,229 $16,952 $38,181 80%
Conservation Limits Rate Increases for a Colorado Utility
8 |
With Conservation Rates Go Up,
But Not Nearly as Much
There is a commonly held belief in the water industry that declining per capita usage due to
water conservation has “forced an increase to rates to account for fewer units of volume billed”
(Craley and Noyes 2013). But the rate increases necessitated by conservation are actually much
smaller than the rate increases that would be necessary to account for population growth in the
absence of conservation. The 21% reduction in average per capita water demand that Westminster
has experienced over the past 30 years has resulted in significant benefit to its customers and
reduced the rate of increase in water and wastewater rates. While water and wastewater rates and
tap fees have increased over that 30 year time period, they have increased much less than they
would have. Customers in Westminster have avoided increasing their water rates by 99% and their
wastewater rates by 18% had this level of water conservation not been achieved. New customers in
Westminster have also avoided an 80% increase in water and sewer tap fees. Yes rates have gone up,
but because of the costs associated with new water supply and infrastructure, they have gone up
much less than they would have.
An answer to the citizen’s question about water conservation and rates had been found and
the result was far more dramatic than the staff had anticipated. The next time a question was
posed about the relationship between conservation and water rates, the Westminster staff was
prepared with an answer: Water rates are going to increase with or without water conservation
because the costs of operating and maintaining the water system continue to increase. However,
water rates increase at a much slower rate if citizens conserve because the city does not need
to purchase expensive new water supply and construct expensive new infrastructure. The
net results of water conservation is a significant cost savings to the customer in water and
wastewater rates and in tap fees.
Each water system is unique, so the results from Westminster may not be applicable to everyone.
Utilities could perform a similar analysis to see the real value of conservation. However, the
over $590 million dollar cost associated with the additional 7,295 AF of demand reveals the
significant hardship associated with expanding water resources supply and wastewater treatment
infrastructure in today’s environment. The high cost also highlights the tremendous value that is
inherent in a utility’s water treatment, wastewater treatment and delivery infrastructure. Imagine
the cost of obtaining water rights and constructing an entire water supply system today. The
cheapest water (by far) is the water we already have and the best way to keep rates and tap fees low
is to conserve the water we already have. The cost of water to providers may vary by region but the
cost of infrastructure remains more consistent. The least expensive infrastructure to build, operate
and maintain is the infrastructure that isn’t needed in the first place. Conserve water or don’t
conserve water – your rates will go up – but if conservation is the lowest cost source of new supply
(and it almost always is) then your rates will go up less than they would have without conservation.
Alliance for Water Efficiency | November, 2013
| 9
References
Beecher, J. 2013. Trends in Consumer Prices for Utilities through 2012. IPU Research Note. Michigan
State University. East Lansing, Michigan.
Craley, R. and C. Noyes. 2013. Water and wastewater rates on the rise. Journal AWWA, August 2013, Vol
105, No. 8, pp. 41-44.
Goetz, M. 2013. Invisible peril: Managing rate issues through public involvement. Journal AWWA, August
2013, Vol 105, No. 8, pp. 34-37.
Alliance for Water Efficiency
300 W. Adams Street, Suite 601
Chicago, Illinois 60606
www.allianceforwaterefficiency.org
ATTACHMENT 4
WORK SESSION
AGENDA ITEM SUMMARY TEMPLATE
Staff: Lance Smith, Utilities Strategic Financial Director
SUBJECT FOR DISCUSSION – Utilities 2016 Capital Improvement Plans and Strategic Financial Plan
Update
EXECUTIVE SUMMARY
The purpose of this agenda item is to provide the Council Finance Committee with an overview of the
planning processes underway within Fort Collins Utilities. The 2016 Capital Improvement Plans (CIPs)
and the process behind them are outlined. The resulting investment projections set the stage for a follow
up discussion in a few months on the long term Utilities Strategic Financial Plan.
The 2016 CIPs have been prioritized in a consistent, quantitative process for the water, wastewater and
stormwater utilities. The 2016 CIP for the electric utility is based largely on a 20 year load assessment
completed earlier this year with Leidos. It is expected that the quantitative prioritization process will be
utilized for the electric utility ahead of the next budget cycle.
Each of these plans is projecting substantial capital investment being needed for each utility over the next
decade. Because the projected levels of investment are not achievable through current operating
revenues alone it will be necessary to further analyze the best means of achieving these operational
needs without negatively impacting the financial integrity of the utilities while maintaining affordable
utilities to the community. This analysis and the long term Utilities Strategic Financial Plan will be the
focus of the follow up discussion in a few months.
GENERAL DIRECTION SOUGHT AND SPECIFIC QUESTIONS TO BE ANSWERED
1. Does the Council Finance Committee support proceeding with the analysis and publication of a
long term Utilities Strategic Financial Plan for each utility within the next few months?
2. Does the Council Finance Committee support the Utilities Strategic Financial Plan assumptions?
BACKGROUND/DISCUSSION
The capital investment required to operate and maintain each of the four utility services provided by the
City to the community requires a long planning horizon and consistent needs assessment and
prioritization in order to ensure that the levels of service established are sustained well into the future.
This process begins with periodically developing and updating Operational Master Plans for each utility.
These plans assess current infrastructure for needs and risks and review expected growth and regulatory
requirements. The Master Plans generate a list of recommended capital projects over the planning
horizon which are then included in the Capital Improvement Plans. The Utility Asset Management
program has developed a rigorous process to identify and prioritize necessary capital investments. This
prioritized list includes the annual capital investment which becomes an input into the long term Strategic
Financial Plan. The financial position of each utility is also reviewed in this step with the output being a
recommended path forward which may involve rate adjustments and future debt issuances in order to
achieve the operational objectives and needs of each utility.
Capital Improvement Plans
Capital Improvement Plan Prioritization Process
The list of projects identified through the Master Planning process serve as a basis for the Capital
Improvement Plans (CIPs) being presented here. These projects are prioritized through the process
outlined in the following flow diagram:
Confirm
Prioritization
Criteria
Prioritization
Criteria Rating
Confirm List of
Projects
Rate Projects
Against Criteria
First Prioritized
List of Projects
Review & Adjust if
Necessary
Final List of
Prioritized
Projects
CPRC Review of
Framework &
Projects
Allocate Capital
Dollars to Projects
Determine
Schedule Based
on Available
Capital
Review &
Approval of
Prioritization
Budget Offers
This process involves many stakeholders throughout the Utilities organization from field and facility staff
to the Executive Director. Throughout the Master Planning and CIP development quantitative analysis is
utilized in the assessment of all capital projects. Industry benchmarking, engineering analysis, and Asset
Management Plans are incorporated wherever possible in the processes.
In 2014, a Capital Project Review Committee (CPRC) was created within the Utilities Service Area to
review the project prioritization prior to budget offers being submitted for the Budgeting for Outcomes
process. The CPRC is composed of the following positions:
Executive Director
Utilities Strategic Finance Director
Water Resources Treatment Operations Manager
Water Engineering & Field Services Manager
Light & Power Operations Manager
The CPRC is responsible for reviewing and approving the capital project prioritization for each enterprise
fund prior to submitting funding requests to the City’s bi-annual Budgeting for Outcomes (BFO) process.
The process outlined above was first utilized for the 10 year CIPs for the three wet utilities in 2014. This
process has been utilized again for the 2016 CIPs for these utilities. While significant progress has been
made in socializing asset management in the electric utility, there was first a need to complete a 20 year
load and capacity study for the electric distribution system before implementing such a process in 2016.
For the 2016 electric utility CIP preliminary allocations were made to asset categories for system renewal,
known annexations were scheduled and the system capacity additions identified the Leidos study were
included. It is fully expected that the process outlined above will be utilized for the electric utility ahead of
the next budget cycle.
The CPRC has reviewed and approved the initial 2016 Capital Improvement Plans for each of the four
utilities. While the 10 year assessment of available capital may require a change in the timing of some
capital investments over the next few months as the Strategic Financial Plans are finalized, the most
immediate capital needs will be submitted through the Budgeting For Outcomes process for the 2017-18
City Budget.
The prioritization criteria identified and weighted by management and a group of subject matter experts
from the water, wastewater and stormwater utilities are:
Relative Weights
Operational Objectives 502 - Water Fund
503 - Wastewater
Fund
504 - Stormwater
Fund
Safety 38% 36% 52%
Regulatory Compliance 29% 24%
Reliability 13% 24% 22%
Sustainability 4% 9% 16%
Customer Satisfaction 7% 7% 10%
Product Quality 9%
Given the City’s commitment to safety and regulatory compliance, these two criteria were weighted the
most heavily in the project prioritization followed by reliability. The relatively low ranking of customer
satisfaction and product quality reflect the previous efforts in both of these categories and the confidence
that both will remain strong into the future mainly through operational practices rather than capital
investments.
10 Year Capital Projections
The 10 year CIP for the Light & Power Fund consists of projects needed to provide adequate substation
and distribution capacity to developing areas of the City, anticipated annexations including the Mulberry
Corridor, operational technology improvements and system renewal of existing substations and
underground distribution assets.
The Mulberry Annexation is expected to cost this utility $15M in asset acquisition and integration costs
over several years with some of the preliminary work potentially starting as soon as 2018 ahead of the
annexation itself to minimize acquisition costs. Two new substations will also be required in 2022 and
2023.
The 10 year CIP for the Water Fund includes the construction of the Halligan Reservoir in 2019-20, an
additional treated water storage facility in 2022 and significant renewal costs for the Poudre Pipeline in
the Poudre Canyon potentially starting in 2018. It also includes significant investment in the distribution
system throughout the City as the renewal rate for the distribution assets is increased. Significant
investment has been made in the Water Treatment Facility since its expansion in 1999 allowing for more
attention to be given to the source of supply and distribution systems over the coming decade.
501 - Light & Power
Project or Program 2017 2018 2019 2020 2021
Substation Improvements $ 445,000 $ 590,000 $ 750,000 $ 620,000 $ 605,000
Distribution System Improvements $ 2,950,000 $ 2,536,000 $ 2,843,000 $ 3,452,000 $ 3,263,000
New Capacity $ 4,654,000 $ 3,628,000 $ 1,034,000 $ 1,770,000 $ 2,970,000
Annexations $ 140,000 $ 3,015,000 $ 3,000,000 $ 3,000,000 $ 3,000,000
Operational Technology & Fiber $ 3,150,000 $ 2,027,000 $ 159,000 $ 161,000 $ 163,000
Total $ 11,339,000 $ 11,796,000 $ 7,786,000 $ 9,003,000 $ 10,001,000
Project or Program 2022 2023 2024 2025 2026
Substation Improvements $ 440,000 $ 440,000 $ 440,000 $ 315,000 $ -
Distribution System Improvements $ 1,785,000 $ 1,839,000 $ 1,894,000 $ 1,950,000 $ 2,008,000
New Capacity $ 7,550,000 $ 13,370,000 $ 3,304,000 $ - $ -
Annexations $ 3,000,000 $ - $ - $ - $ -
Operational Technology & Fiber $ 165,000 $ 167,000 $ 169,000 $ 171,000 $ 173,000
Total $ 12,940,000 $ 15,816,000 $ 5,807,000 $ 2,436,000 $ 2,181,000
The 10 year CIP for the Wastewater Fund consists of increased funding for replacement of the collection
system assets over the next decade and some significant investments in asset improvements over the
next few years at the Water Reclamation Facility. Not shown below are the expected costs associated
with additional nutrient removal regulations that are anticipated just beyond the next decade but which are
anticipated to cost between $70-90M soon thereafter. This expense will be included in the financial
analysis incorporating this CIP.
The 10 year CIP for the Stormwater Fund reflects several large infrastructure projects yet to be built,
including over $100M in a 4 year timespan (2019-2022). It is unlikely that the financial position of this
utility will accommodate such spend over 4 years so further analysis will need to be completed and the
operational impacts of delaying some of this investment analyzed further.
502 - Water
Division 2017 2018 2019 2020 2021
Water Production $ 4,046,000 $ 12,821,000 $ 3,174,000 $ 2,535,000 $ 1,000,000
Water Distribution $ 6,957,000 $ 4,610,000 $ 4,537,000 $ 6,483,000 $ 6,757,000
Water Resources $ 553,000 $ 555,000 $ 13,135,000 $ 14,417,000 $ 2,680,000
Environmental Services $ 1,455,000 $ 1,350,000 $ 50,000 $ 50,000 $ 50,000
Total $ 13,011,000 $ 19,336,000 $ 20,896,000 $ 23,485,000 $ 10,487,000
Division 2022 2023 2024 2025 2026
Water Production $ 16,771,000 $ 3,395,000 $ 14,031,000 $ 1,000,000 $ 1,000,000
Water Distribution $ 6,315,000 $ 7,311,000 $ 7,251,000 $ 7,251,000 $ 7,251,000
Water Resources $ 216,000 $ 222,000 $ 228,000 $ 237,000 $ 183,000
Environmental Services $ 50,000 $ 50,000 $ 50,000 $ 50,000 $ 50,000
Total $ 23,352,000 $ 10,978,000 $ 21,560,000 $ 8,538,000 $ 8,484,000
503 - Wastewater
Division 2017 2018 2019 2020 2021
Water Reclamation $ 7,810,000 $ 10,880,000 $ 5,733,000 $ 3,540,000 $ 3,050,000
Wastewater Collection $ 2,050,000 $ 2,570,000 $ 3,202,000 $ 3,048,000 $ 2,907,000
Environmental Services $ 355,000 $ 30,000 $ 50,000 $ 50,000 $ 50,000
Total $ 10,215,000 $ 13,480,000 $ 8,985,000 $ 6,638,000 $ 6,007,000
Division 2022 2023 2024 2025 2026
Water Reclamation $ 3,050,000 $ 2,050,000 $ 2,050,000 $ 2,259,500 $ 5,362,000
Wastewater Collection $ 3,383,000 $ 3,276,000 $ 3,889,000 $ 4,123,000 $ 3,980,000
Environmental Services $ 50,000 $ 50,000 $ 50,000 $ 50,000 $ 50,000
Total $ 6,483,000 $ 5,376,000 $ 5,989,000 $ 6,432,500 $ 9,392,000
Operating Revenues Available for Capital Investment
Each utility collects operating revenues through monthly charges to its ratepayers. These revenues are
used to operate and maintain each utility including making capital investments in system renewal and
improvements. The chart below looks at the 2015 realized operating revenues for each of the four utilities
and highlights the amount of operating revenue that was available for such capital investments.
The asterisk denotes that for the electric utility the portion of the operating revenue that is necessary to
pay for the purchased power expenses from Platte River and the portion of the Payments In-Lieu of
Taxes (PILOTs) associated with this expense have been removed to show how the remaining portion of
the operating revenues available to Utilities was allocated. This represents 77% of the total operating
revenues collected from electric customers, or $90.4M of the $117.5M total operating revenue. Platte
River allocates those revenues across many of the same categories separately.
Category 2017 2018 2019 2020 2021
Major Capital $ 5,750,000 $ 6,510,000 $ 25,500,000 $ 22,750,000 $ 24,050,000
Minor Capital $ 1,400,000 $ 1,500,000 $ 1,600,000 $ 1,700,000 $ 1,800,000
Boxelder Basin Stormwater Authority $ 350,000 $ 350,000 $ 350,000 $ 350,000 $ 350,000
Stream Rehabilitation $ 350,000 $ 1,400,000 $ 800,000 $ 850,000 $ 900,000
Total $ 7,850,000 $ 9,760,000 $ 28,250,000 $ 25,650,000 $ 27,100,000
Category 2022 2023 2024 2025 2026
Major Capital $ 17,950,000 $ 6,250,000 $ 5,750,000 $ 3,750,000 $ 4,280,000
Minor Capital $ 1,900,000 $ 2,000,000 $ 2,100,000 $ 2,200,000 $ 2,300,000
Boxelder Basin Stormwater Authority $ 350,000 $ 350,000 $ 350,000 $ 350,000 $ 350,000
Stream Rehabilitation $ 950,000 $ 1,000,000 $ 1,050,000 $ 1,100,000 $ 1,150,000
Total $ 21,150,000 $ 9,600,000 $ 9,250,000 $ 7,400,000 $ 8,080,000
33%
46%
35%
19%
19%
11%
10%
15%
9%
11%
7%
5%
7%
12%
13%
27%
6%
5%
6%
16%
10% 15%
30% 34%
0%
20%
40%
60%
80%
100%
Light & Power * Water Wastewater Stormwater
2015 Expenses as % of Operating Revenues
Operating Revenues
Available for Capital
Energy Services
PILOTs
Debt Service
Other Transfers
CS&A
Shortfall of Forecasted Operational Revenues and Development Fees
As the chart above shows, within each Enterprise Fund’s operating revenues there is some capacity to
make capital investment in infrastructure. This is appropriate and necessary to ensure that infrastructure
that has aged beyond its useful life can be renewed. Development fees, or Plant Investment Fees (PIFs),
are also collected as new development occurs within the utility service area. PIFs cover both the
additional cost of connecting the new customers to the existing infrastructure and the portion of existing or
new capacity that will be utilized by the new customers. As the tables above from the CIPs show, capital
investments can vary significantly more than operating revenues from one year to the next.
PIFs also fluctuate significantly from one year to the next. Debt service varies over time as debt is
incurred or retired. Operational expenses also vary year over year depending on the amount of proactive
replacement versus reactive replacement being done. For these reasons a ten year average is
considered when estimating future availability of operating revenues and PIFs for capital investment.
The tables below show how on a year by year basis the portion of operating revenues available for capital
investments and the average annual PIFs are not sufficient to meet the projected capital investments
needed for the utilities even when the current cash reserves are fully utilized above the minimum required
reserves per City Financial Policies. A modest growth in operating expenses of 1.5% is assumed year
over year which is why the amount available through operating revenues decreases over the 10 years.
The first two tables show the electric utility has sufficient capacity within its existing rates and cash
reserve to support the capital investment needed for the first 6 years assuming no other appropriations
are made for use of the reserves.
10 Year Average Operating
Revenues Available for Capital $5,000,000 $3,600,000 $3,000,000 $4,600,000
10 Year Average PIF Revenues
Available for Capital $3,400,000 $4,000,000 $2,900,000 $700,000
10 Year Average Total
Revenues Available for Capital $8,400,000 $7,600,000 $5,900,000 $5,300,000
501 - L&P Fund 2017 2018 2019 2020 2021
Capital Investment from CIP $ 11,340,000 $11,800,000 $7,790,000 $9,000,000 $10,000,000
Available through Operating Revenues
& PIFs
$8,400,000 $8,270,000 $8,150,000 $8,030,000 $7,910,000
Annual Excess / (Shortfall) ($2,940,000) ($3,530,000) $360,000 ($970,000) ($2,090,000)
Available Working Capital $15,000,000 $12,060,000 $8,530,000 $8,890,000 $7,920,000
Running Shortfall $12,060,000 $8,530,000 $8,890,000 $7,920,000 $5,830,000
501 - L&P Fund 2022 2023 2024 2025 2026
Capital Investment from CIP $12,940,000 $15,820,000 $5,810,000 $2,440,000 $2,180,000
Available through Operating Revenues
& PIFs
$7,790,000 $7,670,000 $7,560,000 $7,440,000 $7,330,000
Annual Excess / (Shortfall) ($5,150,000) ($8,150,000) $1,750,000 $5,000,000 $5,150,000
Available Working Capital $5,830,000 $680,000 ($7,470,000) ($5,720,000) ($720,000)
Running Shortfall $680,000 ($7,470,000) ($5,720,000) ($720,000) $4,430,000
The next two tables look at the water utility. Because there is little unappropriated reserves currently
available in this utility, the current rates are not sufficient to meet the anticipated capital needs in 2017.
Over the next decade the shortfall is estimated to be $86M.
The wastewater utility has a significant unappropriated reserve which will allow it to support the capital
investments needed though the first 5 years without a need for a rate adjustment. However, anticipated
new regulatory requirements for nutrient removal and temperature thresholds are expected to require an
additional $60-70M just beyond the ten year planning horizon. This represents an anticipated capital
investment equivalent to 3 years of operating revenue.
502 - Water Fund 2017 2018 2019 2020 2021
Capital Investment from CIP $ 13,010,000 $19,340,000 $20,900,000 $23,490,000 $10,490,000
Available through Operating Revenues
& PIFs
$ 7,600,000 $7,490,000 $7,370,000 $7,260,000 $7,150,000
Annual Excess / (Shortfall) ($5,410,000) ($11,850,000) ($13,530,000) ($16,230,000) ($3,340,000)
Available Working Capital $3,000,000 ($2,410,000) ($14,260,000) ($27,790,000) ($44,020,000)
Running Shortfall ($2,410,000) ($14,260,000) ($27,790,000) ($44,020,000) ($47,360,000)
502 - Water Fund 2022 2023 2024 2025 2026
Capital Investment from CIP $23,350,000 $10,980,000 $21,560,000 $8,540,000 $8,480,000
Available through Operating Revenues
& PIFs
$7,050,000 $6,940,000 $6,840,000 $6,730,000 $6,630,000
Annual Excess / (Shortfall) ($16,300,000) ($4,040,000) ($14,720,000) ($1,810,000) ($1,850,000)
Available Working Capital ($47,360,000) ($63,660,000) ($67,700,000) ($82,420,000) ($84,230,000)
Running Shortfall ($63,660,000) ($67,700,000) ($82,420,000) ($84,230,000) ($86,080,000)
503 - Wastewater Fund 2017 2018 2019 2020 2021
Capital Investment from CIP $ 10,220,000 $13,480,000 $8,990,000 $6,640,000 $6,010,000
Available through Operating Revenues
& PIFs
$ 5,900,000 $5,810,000 $5,720,000 $5,640,000 $5,550,000
Annual Excess / (Shortfall) ($4,320,000) ($7,670,000) ($3,270,000) ($1,000,000) ($460,000)
Available Working Capital $17,000,000 $12,680,000 $5,010,000 $1,740,000 $740,000
Running Shortfall $12,680,000 $5,010,000 $1,740,000 $740,000 $280,000
503 - Wastewater Fund 2022 2023 2024 2025 2026
Capital Investment from CIP $6,480,000 $5,380,000 $5,990,000 $6,430,000 $9,390,000
Available through Operating Revenues
& PIFs
$5,470,000 $5,390,000 $5,310,000 $5,230,000 $5,150,000
Annual Excess / (Shortfall) ($1,010,000) $10,000 ($680,000) ($1,200,000) ($4,240,000)
Available Working Capital $280,000 ($730,000) ($720,000) ($1,400,000) ($2,600,000)
Running Shortfall ($730,000) ($720,000) ($1,400,000) ($2,600,000) ($6,840,000)
The stormwater utility has such a modest unappropriated reserve balance that the capital investment
needed in 2017 immediately produces a funding shortfall.
Is Growth Paying Its Own Way?
Given the forecasted shortfall for capital investment it is reasonable to ask if growth is paying for itself.
Each Enterprise Fund assesses PIFs based on the actual cost of connecting new customers including the
amount of system capacity being allocated to those customers. The determination of what is included in
and how the PIFs are calculated is through a cost of service model similar to the cost of service models
that are updated every two years for existing ratepayers. The PIF model utilized by the three wet utilities
was last reviewed by an outside entity in 2009 and is based on industry best principles. In 2016 a
consultant is being contracted to review and modify as necessary the existing Light & Power PIF model.
The intention of all of the utilities’ PIF models is that growth is paying its own way.
It is important, however, to recognize that capacity is normally built ahead of the new development
requiring such capacity. This is done to both ensure that adequate capacity exists so as to not be a
barrier to economic growth and because capacity is usually added in larger amounts than a single new
customer may need so as to realize the economies of scale for such large capital investments. For
example, the Water Treatment Facility was last expanded in 1999 to its present treatment capacity. This
capacity is expected to be sufficient to serve all customers even through buildout of the water utility’s
service territory. That expansion was paid for through existing cash reserves, the portion of operating
revenues available for capital investment and revenue bonds. As new customers are connected to the
water system the PIFs assessed to those customers will recover the amounts paid by existing customers
for the portion of that capital investment now being allocated to the new customers.
504 - Stormwater Fund 2017 2018 2019 2020 2021
Capital Investment from CIP $ 7,850,000 $9,760,000 $28,250,000 $25,650,000 $27,100,000
Available through Operating Revenues
& PIFs
$ 5,300,000 $5,220,000 $5,140,000 $5,070,000 $4,990,000
Annual Excess / (Shortfall) ($2,550,000) ($4,540,000) ($23,110,000) ($20,580,000) ($22,110,000)
Available Working Capital $2,000,000 ($550,000) ($5,090,000) ($28,200,000) ($48,780,000)
Running Shortfall ($550,000) ($5,090,000) ($28,200,000) ($48,780,000) ($70,890,000)
504 - Stormwater Fund 2022 2023 2024 2025 2026
Capital Investment from CIP $21,150,000 $9,600,000 $9,250,000 $7,400,000 $8,080,000
Available through Operating Revenues
& PIFs
$4,910,000 $4,840,000 $4,770,000 $4,700,000 $4,630,000
Annual Excess / (Shortfall) ($16,240,000) ($4,760,000) ($4,480,000) ($2,700,000) ($3,450,000)
Available Working Capital ($70,890,000) ($87,130,000) ($91,890,000) ($96,370,000) ($99,070,000)
Running Shortfall ($87,130,000) ($91,890,000) ($96,370,000) ($99,070,000) ($102,520,000)
Next Step: Strategic Financial Planning
Estimated Rate Increases Required to Avoid Issuing Debt
Each of the four utilities show a shortfall in available funding for the needed capital investment at some
point over the next decade with the water and stormwater utilities each showing a shortfall in every year.
This is only the initial step in developing the Strategic Financial Plan. While it does show that there will
need to be rate increases and debt issuances over the coming decade in order to achieve the capital
investment necessary, a reasonable path forward will be developed for each utility and presented to the
City Council for further consideration.
The next table shows the amount of annual rate increase that would be necessary to meet these
shortfalls year by year for each utility. This assumes there is no debt issuance for any utility and
operational expenses increases with inflation at 1.5% annually. Because capital investments fluctuate
from one year to the next, rate decreases are also necessary from year to year to avoid building up
excessive reserves. While the average annual rate change only exceeds 6% for the wastewater utility
and the net 10 year rate increases are relatively small, the year over year volatility would not be
acceptable to our community.
Relative Rate Increases
Fort Collins citizens and businesses benefit from the low cost of utility services along with many
neighboring communities. Through long term planning and prudent operations, the City has maintained
these competitive rates through a rate philosophy of gradual, modest rate adjustments. Below is a table
comparing the recent rate increases of several neighboring communities to those of Fort Collins Utilities.
Utility 2017 2018 2019 2020 2021 2022 2023 2024 2025 2026
10 Yr Ave Annual
Rate Change
Light & Power -38% 81% -11% 4% 3% 9% 8% -25% -11% -1% 2%
Water 8% 29% 4% 6% -28% 39% -27% 32% -29% 0% 4%
Wastewater -53% 179% -14% -8% -2% 2% -4% 3% 2% 12% 12%
Stormwater 4% 26% 97% -7% 4% -16% -37% -2% -9% 4% 6%
2014 2015 2016 2014 2015 2016
Ft Collins 2.0% 1.9% 3.2% 4.0% 0.0% 0.0%
Loveland 8.4% 0.9% 5.5% 19.0% 13.1% 9.0%
Longmont 8.2% 4.9% 0.0% 4.5% 0.0% 7.0%
Greeley 5.8% 6.6% ‐4.4% 7.9% 3.7% 0.7%
Boulder 5.8% 6.6% ‐4.4% 3.0% 3.9% 4.7%
Colorado Springs 0.0% 3.7% 5.7% 11.2% 11.7% 0.0%
Electric Water
Relative rate increases can be misleading if not put into context of actual charges. The table below
shows the actual charges for a typical residential customer.
2014 2015 2016 2014 2015 2016
Ft Collins 3.0% 3.0% 3.0% 0.0% 0.0% 0.0%
Loveland 3.9% 11.1% 21.7% 0.0% 9.6% 9.6%
Longmont 16.7% 16.4% 15.1% 0.0% 68.0% 0.0%
Greeley ‐2.1% ‐0.7% 3.4% 0.0% 14.6% 0.0%
Boulder 5.0% 1.2% 27.5% 3.0% 2.9% 75.0%
Colorado Springs 0.0% 0.0% 0.0% N/A N/A N/A
Wastewater Stormwater
2016 2016 2016 2016 2016
Ft Collins $ 68.21 $ 43.57 $ 35.07 $ 14.26 $ 161.11
Loveland $ 67.01 $ 34.00 $ 25.43 $ 12.48 $ 138.92
Longmont $ 63.25 $ 31.47 $ 33.63 $ 13.05 $ 141.40
Greeley $ 79.67 $ 51.35 $ 20.62 $ 6.45 $ 158.09
Boulder $ 79.67 $ 35.84 $ 29.08 $ 13.46 $ 158.05
Colorado Springs $ 85.46 $ 77.82 $ 31.27 N/A $ 194.55
Electric Water Wastewater Stormwater Total
Debt Schedules
Given the anticipated funding shortfall to meet the expected capital investments required in the Enterprise
Funds over the next decade and the variable nature of such capital investments, it will be necessary from
time to time to issue revenue bonds in a prudent manner to minimize rate adjustments and still ensure
that adequate capacity exists for new development and existing assets are renewed as needed to
maintain the level of service and reliability expected by our community. Below are the annual debt
service costs for all current debt by Enterprise Fund. The annual debt service costs depend on both the
term of the debt issuance (typically 10 or 20 years) and the interest rate which in turn depends on the
bond rating at issuance. Just for some context, a $10M debt issuance may cost $700-900K annually for a
20 year term or $1.1-1.3M for a 10 year term.
The Light & Power Fund issued its first debt in many years in 2010 to pay for the portion of the Advanced
Meter Fort Collins project not covered through the matching federal grants. This debt has a current bond
rating of AA- and will be retired in 2020.
The Water Fund has a longer history of issuing debt for capital investment. In part because the size of
some of the capital projects can exceed several years of operating revenue, making it difficult to have
sufficient cash reserves for such large investments. The Water Enterprise Fund debt has a current bond
rating of AAA. As the chart shows this Fund has carried significant debt service costs in the recent past
and most of this debt will be retired over the next few years.
$0
$500,000
$1,000,000
$1,500,000
$2,000,000
$2,500,000
2006 2008 2010 2012 2014 2016 2018 2020 2022 2024 2026
Annual Debt Service
501 - Light & Power Fund
The Wastewater Enterprise Fund has issued several 20 year bonds. The bond rating for the Wastewater
utility is currently AA+.
The Stormwater Fund has issued debt to support the initial build-out of the stormwater infrastructure. The
bond rating for the Stormwater Fund is AA+, as well. The debt service costs for this Fund will be reduced
over the next few years as existing debt is retired. This will modestly increase the amount of operating
revenue available for either new debt service or directly for capital investments.
$0
$1,000,000
$2,000,000
$3,000,000
$4,000,000
$5,000,000
$6,000,000
$7,000,000
$8,000,000
2006 2008 2010 2012 2014 2016 2018 2020 2022 2024 2026
Annual Debt Service
502 - Water Fund
2002 GO WATER
2009 WATER
2008 WATER
1998 WATER
2003 WATER SUBORD
1997 WATER
1999 WATER
$0
$1,000,000
$2,000,000
$3,000,000
$4,000,000
$5,000,000
$6,000,000
2006 2008 2010 2012 2014 2016 2018 2020 2022 2024 2026
Annual Debt Service
503 - Wastewater Fund
2010 SEWER
2009 SEWER
2005 SEWER
1992 SEWER
Conclusion
As shown there will be a need for considerable capital investment in each of the utility services in the
coming decade. This is not unexpected given the growth of our community and the high levels of service
required to support its economic development and sustainability. The low utility rates and high level of
customer satisfaction are the results of City Leadership, both past and present, showing tremendous
foresight and commitment to these municipal services and to the planning, operational and customer
focused efforts of City staff. This update to the Council Finance Committee is intended to maintain this
tradition through a long term Utilities Strategic Financial Plan.
Staff will continue the analysis from inputting the capital needs into the long term financial models for
each utility. These capital investment needs along with the projected trends in operational costs and
uncertainties in revenue and expense projections will be modeled to understand the rate implications and
need for debt issuances over the next decade. The model inputs, methodology and outputs will then be
presented to the Council Finance Committee within a few months including a recommended path for each
utility for the 2017-18 City Budget being considered by the City Manager and the Mayor and City Council.
Attachments
Light & Power Enterprise Fund Capital Improvement Plan
Water Enterprise Fund Capital Improvement Plan
Wastewater Enterprise Fund Capital Improvement Plan
Stormwater Enterprise Fund Capital Improvement Plan
$0
$500,000
$1,000,000
$1,500,000
$2,000,000
$2,500,000
$3,000,000
$3,500,000
$4,000,000
$4,500,000
2006 2008 2010 2012 2014 2016 2018 2020 2022 2024 2026
Annual Debt Service
504 - Stormwater Fund
2011 STORMWATER
2007B STORMWATER
2007A
STORMWATER
2002 STORMWATER
REFUND
ATTACHMENT 5
COUNCIL FINANCE COMMITTEE
AGENDA ITEM SUMMARY
Staff: Lance Smith, Utilities Strategic Financial Director
Date: June 20, 2016
SUBJECT FOR DISCUSSION Utilities 2016 Strategic Financial Plan Update
EXECUTIVE SUMMARY
The purpose of this agenda item is to provide the Council Finance Committee with an update on
the 2016 Utilities Strategic Financial Plan as a follow up to the discussion on April 18, 2016 on
each utility’s Capital Improvement Plan (CIP). As stated in that Agenda Item Summary:
“Each of these plans [CIPs] is projecting substantial capital investment being needed for each
utility over the next decade. Because the projected levels of investment are not achievable
through current operating revenues alone it will be necessary to further analyze the best means of
achieving these operational needs without negatively impacting the financial integrity of the
utilities while maintaining affordable utilities to the community. This analysis and the long term
Utilities Strategic Financial Plan will be the focus of the follow up discussion in a few months.”
Recommendations for achieving the capital investments proposed in the CIPs while maintaining
the financial health of each utility, along with the bond rating, through modest rate adjustments
are discussed below and in the presentation. With the exception of the Stormwater Fund, the
recommendation achieves these objectives within the next decade. The Stormwater CIP will
require 15 years to complete the work targeted within the next decade in order to achieve these
objectives.
GENERAL DIRECTION SOUGHT AND SPECIFIC QUESTIONS TO BE ANSWERED
1. Does the Council Finance Committee support the Utilities Strategic Financial Planning
recommendations?
BACKGROUND/DISCUSSION
At the April 18, 2016 Council Finance Committee the “Utilities Capital Improvement Plan and
Strategic Financial Plan Update” outlined the full planning process for capital projects beginning
with the Master Planning efforts, including the prioritized CIPs and how the process continues
with the Strategic Financial Plan being developed. That discussion showed why none of the
utility funds have adequate Available Reserves 1 to achieve the proposed capital projects over the
1 Available Reserves are the portion of the Fund Balance that is not necessary to meet Bond covenants or the City’s
Minimum Reserve Financial Policy, and is not currently appropriated for another purpose.
coming decade. Thus it will be necessary to adjust rates and consider issuing debt before
considering also delaying some of the capital projects beyond 10 years.
Several Next Steps were identified then which are being discussed herein. The Next Steps were
to:
1. Incorporate the 10 year capital projections into the long term financial model for each
utility
2. Perform scenario analyses to understand cash vs. debt funding impacts on rates, reserves,
debt capacity and the financial position of each Enterprise Fund
3. Develop recommendations on rate increases and debt issuances to meet the expected
needs of the Fund
Incorporate the 10 Year CIP into Financial Models
Since the meeting in April, the capital investment projections for 2017-2026 have been entered
into a long term financial planning model for each utility. This model considers a 21 year
horizon (2006 – 2026) beginning 10 years ago and projecting forward 10 years from today. The
10 years of historical analysis provides the basis for the 10 year forward projection for each
revenue and expense.
Perform Scenario Analyses
There are several financial mechanisms available to cover the incremental capital investments.
Any Available Reserves can be appropriated to the specific capital projects ensuring their
adequate funding. Any operating income will increase the Available Reserves. Rate
adjustments provide a direct way to increase operating income. Available Reserves can also be
increased by issuing debt through revenue bonds. The balance between these mechanisms is the
objective of the stochastic model.
The financial model has several financial objectives:
Maintaining adequate Operating Income and Reserve Minimums are necessary.
It is preferred that the City maintain, if not improve, its bond rating wherever possible
including the Utility Enterprise Funds.
Rate spikes are undesirable because of the impact such adjustments can have on
residential and commercial customers.
An order of preference is necessary when considering rates, Available Reserves and Debt in the
model. Because rate adjustments provide the most direct communication with ratepayers that
costs are increasing, rate adjustments were considered first by themselves. This is consistent
with the assumption that rate adjustments will always be a consideration. Then because the CIP
was prioritized to respect that prioritization it is necessary to also consider debt in the sources
available to increase the Available Reserves. Lastly, adjustments to the capital investment over
the next decade were considered if it just is not financially feasible to respect the prioritization of
the CIP.
1. Scenario 1 – This scenario first considers if it is possible to complete the proposed capital
projects within the next 10 years (2017 – 26) by only adjusting rates and not issuing any
new debt. If this is achievable with modest rate adjustments then this is the
recommended path for that specific utility.
2. Scenario 2 – This scenario acknowledges that it may not be possible to achieve the
objectives through Scenario 1 and considers also issuing debt to raise of the necessary
capital. If this is achievable through manageable debt service costs and modest rate
adjustments then it is the recommendation.
3. Scenario 3 – This scenario is considered when there is no combination of modest rate
adjustments and serviceable debt issuances to achieve the capital projects and maintain
the financial health of the utility. In this scenario adjustments to the 10 year capital spend
are considered – either smoothing out the capital spend evenly across those 10 years or
extending the time horizon out beyond 10 years.
Develop Recommendations
Light & Power
The projected 10 Year CIP includes $90M of new capital needs for the anticipated system
demands over the decade. This represents a 10-15% increase over the previous decade’s capital
investment.
$-
$2,000,000
$4,000,000
$6,000,000
$8,000,000
$10,000,000
$12,000,000
$14,000,000
$16,000,000
$18,000,000
2017 2018 2019 2020 2021 2022 2023 2024 2025 2026
Annual Capital Investment
501 - Light & Power Fund
Operational Technology & Fiber
Annexations
New Capacity
Substation Improvements
Distribution System Improvements
Ave. Capital Investment 2017-26
Historical Ave Capital 2006-15
Such a change from recent history should be manageable through modest rate increases alone.
The dashboard below shows how this is viable. The upper left corner is a chart showing
potential annual rate increases as being less than 5%. The upper right corner is a chart showing
the annual operating income for the fund. Each Enterprise is expected to have adequate
operating income. The bottom right corner shows a chart of the total outstanding principal debt.
In this analysis no additional debt was issued and the outstanding debt is fully retired in 2020.
The bottom left corner shows the Available Reserves. Here the capital investment drops off
significantly in the last few years resulting in an increased operating income which results in the
Available Reserves building up quickly. This analysis will be updated every two years to
monitor if any adjustments are necessary.
Recommendation: Scenario 1 will allow for the additional capital needs through modest rate
adjustments without the anticipated need of issuing debt over the coming decade.
Water
The Water Enterprise Fund has a CIP with $160M which represents twice the historical average
annual spend has been.
0.0%
1.0%
2.0%
3.0%
4.0%
5.0%
6.0%
7.0%
8.0%
9.0%
10.0%
Rate Increase
($5,000,000)
($2,500,000)
$0
$2,500,000
$5,000,000
$7,500,000
$10,000,000 Operating Income
$0
$10,000,000
$20,000,000
$30,000,000
$40,000,000
$50,000,000
$60,000,000
$70,000,000
2006 2008 2010 2012 2014 2016 2018 2020 2022 2024 2026
Available Reserves
0
5000000
10000000
15000000
20000000
25000000
30000000
35000000
2006 2008 2010 2012 2014 2016 2018 2020 2022 2024 2026
Outstanding Debt
This utility also has low Available Reserves which limits short term financial agility. The CIP
also ramps up quickly which together make it infeasible to have modest rate adjustments alone
(Scenario 1) and achieve the operational needs for the CIP. The dashboard below shows the
negative Available Reserves and large rate increases. The build-up of Available Reserves may
make it necessary to adjust rates downward as well in the last few years.
Next, issuing debt along with modest rate increases was considered. This Scenario (Scenario 2)
does result in a feasible path. However, as the dashboard below shows, operating income
remains negative.
$-
$5,000,000
$10,000,000
$15,000,000
$20,000,000
$25,000,000
2017 2018 2019 2020 2021 2022 2023 2024 2025 2026
Annual Capital Investment
502 - Water Fund Environmental Services
Water Resources
Water Distribution
Water Production
Ave. Capital Investment 2017-26
Historical Ave Capital 2006-15
($5,000,000)
$0
$5,000,000
$10,000,000
$15,000,000
$20,000,000 Operating Income
$0
$10,000,000
$20,000,000
$30,000,000
$40,000,000
$50,000,000
$60,000,000
2006 2008 2010 2012 2014 2016 2018 2020 2022 2024 2026
Outstanding Debt
($10,000,000)
$0
$10,000,000
$20,000,000
$30,000,000
$40,000,000
$50,000,000
$60,000,000
$70,000,000
$80,000,000
$90,000,000
2006 2008 2010 2012 2014 2016 2018 2020 2022 2024 2026
Available Reserves
0.0%
5.0%
10.0%
15.0%
20.0%
25.0%
30.0% Rate Increase
Next it was assumed that the annual capital spend over the coming decade can be smoothed to
near the average annual spend each year (Scenario 3). This change respects the prioritization in
the CIP and accomplishes the same infrastructure in 2026 as the CIP. The dashboard below
shows how this change reduces the amount of debt needing to be issued from $55-70M to $50-
60M and results in positive operating income.
Recommendation: Scenario 3 (immediately above) which will accomplish the financial
objectives while completing the CIP over the coming decade.
Wastewater
The slight reduction in the estimated capital investment over the coming decade compared to the
previous decade is the result of the Mulberry rebuild.
($5,000,000)
($3,000,000)
($1,000,000)
$1,000,000
$3,000,000
$5,000,000
$7,000,000 Operating Income
$0
$10,000,000
$20,000,000
$30,000,000
$40,000,000
$50,000,000
$60,000,000
$70,000,000
2006 2008 2010 2012 2014 2016 2018 2020 2022 2024 2026
Outstanding Debt
$0
$5,000,000
$10,000,000
$15,000,000
$20,000,000
$25,000,000
$30,000,000
$35,000,000
$40,000,000
2006 2008 2010 2012 2014 2016 2018 2020 2022 2024 2026
Available Reserves
0.0%
1.0%
2.0%
3.0%
4.0%
5.0%
6.0%
7.0% Rate Increase
($5,000,000)
($3,000,000)
($1,000,000)
$1,000,000
$3,000,000
$5,000,000
$7,000,000 Operating Income
$0
$10,000,000
$20,000,000
$30,000,000
$40,000,000
$50,000,000
$60,000,000
The minor change in the average annual capital investment should be manageable through rate
adjustments alone. This Fund also has healthy Available Reserves allowing for more financial
agility if needed in an emergency. The dashboard below shows how Scenario 1 is sufficient to
meet the operational needs and maintain the current levels of service.
The bottom left corner shows a sizable build-up of Available Reserves over the next decade.
This is intentional to address new nutrient removal and temperature regulations driven capital
projects in 2027-30 estimated to cost $60-80M in addition to ongoing system renewal.
Recommendation: Modest rate adjustments should be sufficient to cover capital investment in
the next decade without the need to issue additional debt for this fund.
Stormwater
$-
$2,000,000
$4,000,000
$6,000,000
$8,000,000
$10,000,000
$12,000,000
$14,000,000
$16,000,000
2017 2018 2019 2020 2021 2022 2023 2024 2025 2026
Annual Capital Investment
503 - Wastewater Fund
Environmental Services
Wastewater Collection
Water Reclamation
Ave. Capital Investment 2017-26
Historical Ave Capital 2006-15
$0
$1,000,000
$2,000,000
$3,000,000
$4,000,000
$5,000,000
$6,000,000
$7,000,000
$8,000,000
$9,000,000
$10,000,000 Operating Income
$0
$10,000,000
$20,000,000
$30,000,000
$40,000,000
$50,000,000
$60,000,000
2006 2008 2010 2012 2014 2016 2018 2020 2022 2024 2026
Outstanding Debt
$0
$20,000,000
$40,000,000
$60,000,000
$80,000,000
$100,000,000
2006 2008 2010 2012 2014 2016 2018 2020 2022 2024 2026
Available Reserves
0.0%
2.0%
4.0%
6.0%
8.0%
The Stormwater Enterprise Fund has spent just over $5M per year on capital investments in the
previous decade. The 2017-26 CIP requires just over $15M per year or 3 times the current rate
of investment.
This utility has low Available Reserves which limits the financial agility of the utility in the short
term. The CIP is also heavily focused on the first 5 years ($71M invested in 2017-21 and $29M
in 2022-26). Together these challenges make it infeasible to address the CIP goals through rates
alone. The dashboard below for this Scenario (Scenario 1) shows that Available Reserves
immediately turn negative and operating income jumps with the large rate adjustments.
Rate adjustments are not effective in the situation this utility is in with high operating income,
low Available Reserves, and annual operating revenues of just $15M, or the same amount of
capital investment requested per year although it is tightly focused on 4 years in the middle.
$-
$5,000,000
$10,000,000
$15,000,000
$20,000,000
$25,000,000
$30,000,000
2017 2018 2019 2020 2021 2022 2023 2024 2025 2026
Annual Capital Investment
504 - Stormwater Fund Boxelder Basin Stormwater
Authority
Stream Rehabilitation
Minor Capital
Major Capital
Ave. Capital Investment 2017-26
Historical Ave Capital 2006-15
$0
$5,000,000
$10,000,000
$15,000,000
$20,000,000
$25,000,000 Operating Income
$0
$10,000,000
$20,000,000
$30,000,000
$40,000,000
$50,000,000
$60,000,000
2006 2008 2010 2012 2014 2016 2018 2020 2022 2024 2026
Outstanding Debt
($30,000,000)
($25,000,000)
($20,000,000)
($15,000,000)
($10,000,000)
($5,000,000)
$0
$5,000,000
$10,000,000
2006 2008 2010 2012 2014 2016 2018 2020 2022 2024 2026
Available Reserves
0.0%
20.0%
40.0%
60.0%
80.0%
100.0%
120.0% Rate Increase
Rates and debt (Scenario 2) are shown in the dashboard below. Available Reserves are not
sufficient even with the very large debt issuance ($80-90M within the first 5 years) and 10% rate
increases.
Next it was considered how the CIP could be modified while respecting the prioritization of the
investments. Because the increase in the average annual capital investment is increasing so
much from $5M to $15M per year smoothing the investment evenly over the 10 years is not
going to be adequate. Instead stretching the timeline from 10 years out to 15 years was
considered (Scenario 3). The dashboard below shows how effective this approach is at achieving
the financial objectives albeit over a longer time period.
Recommendation: Scenario 3 which reduces the near term debt issuance down from $80-90M to
$40-50M by extending the time horizon out 5 years to 2031.
Where Are We In the Planning Process?
As the CIPs are incorporated into developing the 2016 Utilities Strategic Financial Plan there is a
need for some back and forth discussions between the Utility Executive Director, Operations
$0
$1,000,000
$2,000,000
$3,000,000
$4,000,000
$5,000,000
$6,000,000
$7,000,000
$8,000,000
$9,000,000 Operating Income
$0
$10,000,000
$20,000,000
$30,000,000
$40,000,000
$50,000,000
$60,000,000
$70,000,000
$80,000,000
$90,000,000
$100,000,000
2006 2008 2010 2012 2014 2016 2018 2020 2022 2024 2026
Outstanding Debt
($10,000,000)
($5,000,000)
$0
$5,000,000
$10,000,000
$15,000,000
$20,000,000
$25,000,000
$30,000,000
$35,000,000
$40,000,000
2006 2008 2010 2012 2014 2016 2018 2020 2022 2024 2026
Available Reserves
0.0%
2.0%
4.0%
6.0%
8.0%
10.0%
12.0% Rate Increase
$0
$1,000,000
$2,000,000
Managers and Finance around what may be a manageable adjustment to the annual capital
investment while maintaining the current levels of service being provided to the community.
This is where we are at now in the whole planning process.
The Scenario Analyses suggested the preferred financial strategy to the CIP. Now the
Operations Managers need to consider what this approach would mean in terms of impacts to the
current levels of service and what may be adjustable or not. Subsequent modeling efforts may be
needed if the preferred financial strategy is not operationally feasible.
On the version of the process map presented in April shown below the red loop represents where
we are currently at in the planning process:
Conclusion
The 2016 CIPs included significant increases in anticipated capital investments for two of the
utilities over the previous decade’s investment level. These two utilities also are the same two
utilities with low Available Reserves. Managing the financial health of these two utilities, Water
and Stormwater, while maintaining the current levels of service will require rate adjustments,
debt issuances and some adjustments to the CIPs.
The other two utilities, Light & Power and Wastewater, are expecting modest rate adjustments
may be necessary over the next 10 years, but there is not expected to be a need to issue debt in
these two utilities over the next decade.
Utility
Available
Reserves (in $M)
2015 Operating
Expenses (in $M)
Days Cash on Hand in
Available Reserves
Capital Spend
2006-15 (in $M)
Capital Spend
2017-26 (in $M)
% Increase /
(Decrease)
Light & Power 16.4 38.8 154 80.5 85 5.6%
Water 4.4 23.3 69 73.9 152.1 105.8%
Wastewater 18.5 15.8 427 87.7 84.8 -3.3%
Stormwater 4.1 9.9 151 56.3 156.5 178.0%
Staff will continue to keep the Council Finance Committee and the entire City Council informed of the
biannual updates and other changes to the Utilities Strategic Financial Plan. The 2016 Utilities Strategic
Financial Plan will be published once the current iterative step between Finance and Operations is agreed
upon within the next few months.
ATTACHMENTS
Attachment 1 – CFC Presentation for June 20, 2016
Attachment 2 – CFC AIS on “Utilities Capital Improvement Plans and Strategic Financial Plan
Update” from April 18, 2016
OPTION NOT ADOPTED
ON FIRST READING
-1-
OPTION 2
(Increase in Fixed Monthly Charge Only)
ORDINANCE NO. 122, 2016
OF THE COUNCIL OF THE CITY OF FORT COLLINS
AMENDING CHAPTER 26 OF THE CODE OF THE CITY OF FORT
COLLINS TO REVISE ELECTRIC RATES, FEES, AND CHARGES
WHEREAS, the City Council is empowered and directed by Article XII, Section 6, of the
City Charter to fix, establish, maintain and provide for the collection of such rates, fees or
charges for utility services furnished by the City as will produce revenues sufficient to pay the
costs, expenses and other obligations of the electric utility, as set forth therein; and
WHEREAS, the rates, fees or charges for utility services set forth herein are necessary to
produce sufficient revenues to provide the utility services described herein; and
WHEREAS, the revenue from the rates, fees or charges for utility services set forth
herein shall be used to defray the costs of providing such utility services as required by the
Charter and the City Code; and
WHEREAS, the City purchases bulk wholesale electric power from Platte River Power
Authority (“PRPA”) pursuant to an Amended Contract for Supply of Electric Power and Energy,
dated September 1, 2010; and
WHEREAS, PRPA costs are increasing due to reduced wholesale market prices and
surplus sales, increased costs for coal, and increased operating costs for aging plants; and
WHEREAS, PRPA will increase the City’s wholesale cost of power approximately 3.0%
in 2017; and
WHEREAS, the increased wholesale power cost will require an average 2.2% rate
increase and increased local distribution costs will require an additional average 1.25% rate
increase, for a total City electric rates increase in 2017 of 3.45% in order to remain consistent
with Article XII, Section 6, of the City Charter; and
WHEREAS, the proposed rate increase will vary by customer class based on the cost of
service to each class; and
WHEREAS, in addition to adjusting the electric rates in the City Code, Utilities staff has
identified formatting and maintenance updates to Chapter 26 of the City Code necessary to
improve the clarity with which electric rates are stated; and
WHEREAS, the Energy Board considered the proposed electric rates, fees, and charges,
and language clarifications for 2017 at its October 6, 2016 regular meeting and provided a
recommendation of approval to City Council; and
OPTION NOT ADOPTED
ON FIRST READING
-2-
WHEREAS, the City Manager and staff have recommended to the City Council the
following electric rate adjustments and City Code rate language clarifications for all electricity
used by GS50 and GS750 rate class customers on or after January 1, 2017, and for all other
customer classes for all billings issued with meter readings on or after January 1, 2017; and
WHEREAS, based on the foregoing, it is the desire of the City Council to amend Chapter
26 of the City Code to revise the electric rates, fees and charges.
NOW, THEREFORE, BE IT ORDAINED BY THE COUNCIL OF THE CITY OF
FORT COLLINS as follows:
Section 1. That the City Council hereby makes and adopts the determinations and
findings contained in the recitals set forth above.
Section 2. That Sections 26-464 (c)-(f), (p), (r) and (s) of the Code of the City of Fort
Collins are hereby amended to read as follows:
Sec. 26-464. Residential energy service, schedule R.
. . .
(c) Monthly rate. The monthly rates for this schedule shall be the sum of the
following charges:
(1) Fixed Charge Per account $5.07
$6.94
(2) Distribution facilities charge Per kWh $0.0238
(3) Energy and demand charge
a. Summer. During the summer season billing months of June, July and August, with the
summer season billing month determined by the month the meter is read, and provided
that no customer shall be billed more than three (3) full billing cycles at the summer
rate.
1. Tier 1 - for the first five hundred (500) kilowatt hours
per month
2. Tier 2 - for the next five hundred (500) kilowatt hours
per month
3. Tier 3 - for all additional kilowatt hours per month
Per kWh $0.0632
$0.0634
Per kWh $0.0804
$0.0807
Per kWh $0.1146
$0.1150
b. Non-summer. During the non-summer season billing months of January through May
and September through December.
1. Tier 1 - for the first five hundred (500) kilowatt hours
per month, per kWh
2. Tier 2 - for the next five hundred (500) kilowatt hours
Per kWh $0.0570
$0.0583
Per kWh $0.0611
OPTION NOT ADOPTED
ON FIRST READING
-3-
per month, per kWh
3. Tier 3 - for all additional kilowatt hours per month, per
kWh
$0.0625
Per kWh $0.0703
$0.0719
(4) Payment in lieu of taxes (PILOT) and franchise.
A charge based on all monthly service charges billed pursuant to this
Section
6 percent
(d) Medical assistance program.
. . .
(3) The discounted monthly rates for customers with electrical durable
medical equipment only shall be the sum of the following charges:
a. Fixed Charge Per account $5.07
$6.94
b. Distribution facilities charge Per kWh $0.0238
c. Energy and demand charge
1. Summer. During the summer season billing months of June, July and August, with the
summer season billing month determined by the month the meter is read, and provided
that no customer shall be billed more than three (3) full billing cycles at the summer
rate.
(a) Tier 1 - for the first five hundred (500) kilowatt hours
per month
(b) Tier 2 - for the next five hundred (500) kilowatt hours
per month
(c) Tier 3 - for all additional kilowatt hours per month
Per kWh $0.0357
$0.0358
Per kWh $0.0804
$0.0807
Per kWh $0.1146
$0.1150
2. Non-summer. During the non-summer season billing months of January through May
and September through December.
(a) Tier 1 - for the first five hundred (500) kilowatt hours
per month, per kWh
(b) Tier 2 - for the next five hundred (500) kilowatt hours
per month, per kWh
(c) Tier 3 - for all additional kilowatt hours per month, per
kWh
Per kWh $0.0311
$0.0318
Per kWh
$0.0611
$0.0625
Per kWh $0.0703
$0.0719
d. Payment in lieu of taxes (PILOT) and franchise.
A charge based on all monthly service charges billed pursuant to this
Section
6 percent
OPTION NOT ADOPTED
ON FIRST READING
-4-
(4) The discounted monthly rates for customers with medical needs requiring
air conditioning only shall be the sum of the following charges:
a. Fixed Charge Per account $5.07
$6.94
b. Distribution facilities charge Per kWh $0.0238
c. Energy and demand charge
1. Summer. During the summer season billing months of June, July and August, with
the summer season billing month determined by the month the meter is read, and
provided that no customer shall be billed more than three (3) full billing cycles at
the summer rate.
(a) Tier 1 - for the first five hundred (500) kilowatt hours
per month
(b) Tier 2 - for the next five hundred (500) kilowatt hours
per month
(c) Tier 3 - for all additional kilowatt hours per month
Per kWh $0.0350
$0.0351
Per kWh $0.0444
$0.0446
Per kWh $0.1146
$0.1150
2. Non-summer. During the non-summer season billing months of January through
May and September through December.
(a) Tier 1 - for the first five hundred (500) kilowatt hours
per month, per kWh
(b) Tier 2 - for the next five hundred (500) kilowatt hours
per month, per kWh
(c) Tier 3 - for all additional kilowatt hours per month, per
kWh
Per kWh $0.0570
$0.0583
Per kWh
$0.0611
$0.0625
Per kWh $0.0703
$0.0719
d. Payment in lieu of taxes (PILOT) and franchise.
A charge of all monthly service charges billed pursuant to this Section
6 percent
(5) The discounted monthly rates for customers with electrical durable
medical equipment and medical needs requiring air conditioning shall be the sum
of the following charges:
a. Fixed Charge Per account $5.07
$6.94
b. Distribution facilities charge Per kWh $0.0238
c. Energy and demand charge
1. Summer. During the summer season billing months of June, July and August, with
the summer season billing month determined by the month the meter is read, and
provided that no customer shall be billed more than three (3) full billing cycles at
the summer rate.
OPTION NOT ADOPTED
ON FIRST READING
-5-
(a) Tier 1 - for the first five hundred (500) kilowatt hours
per month
(b) Tier 2 - for the next five hundred (500) kilowatt hours
per month
(c) Tier 3 - for all additional kilowatt hours per month
Per kWh $0.0229
Per kWh $0.0291
$0.0292
Per kWh $0.1146
$0.1150
2. Non-summer. During the non-summer season billing months of January through
May and September through December.
(a) Tier 1 - for the first five hundred (500) kilowatt hours
per month, per kWh
(b) Tier 2 - for the next five hundred (500) kilowatt hours
per month, per kWh
(c) Tier 3 - for all additional kilowatt hours per month, per
kWh
Per kWh $0.0311
$0.0318
Per kWh
$0.0611
$0.0625
Per kWh $0.0703
$0.0719
a. Payment in lieu of taxes (PILOT) and franchise.
A charge based on all monthly service charges billed pursuant to this
Section
6 percent
. . .
(e) Renewable resource. Renewable energy resources, including, but not limited to,
energy generated by the power of wind, may be offered on a voluntary basis to customers
at the premium per kilowatt hour set forth in this Subsection (e). The utility may establish
and offer voluntary programs designed to increase and enhance the use of energy
generated by renewable energy resources in support of Council-adopted policy applicable
to the utility.
Per kWh $0.024
$0.025
(f) Excess capacity charge. The monthly capacity charge kilowatt set forth in this
Subsection (f) may be added to the above charges for service to intermittent loads in
accordance with the provisions of the Electric Service Standards.
Per kW $2.00
$2.09
. . .
(p) Net metering.
. . .
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(5) The customer-generator's consumption of energy from the utility and
production of energy that flows into the utility's distribution system shall be
measured on a monthly basis. The energy consumed from the utility by the
customer-generator shall be billed at the applicable seasonal tiered rate as outlined
in Subsection (c) of this Section. The energy produced by the customer-generator
shall be credited to the customer monthly as follows:
a. Distribution facilities credit Per kWh $0.0238
b. Energy and demand credit Per kWh $0.0632
$0.0634
(6) TOU rates, for customer-generators participating in a qualifying "time-of-
use" (TOU) rate study, consumption of energy from the utility and production of
energy that flows into the utility's distribution system shall be measured on a
monthly basis. The energy consumed from the utility by the customer-generator
shall be billed at the applicable study rates under Subsection (s) of this Section.
The energy produced by the customer-generator shall be credited to the customer
monthly as follows:
a. Energy and demand credit – summer season billing months
1. On-Peak (Mon-Fri, 2 pm to 7 pm, excluding holidays) Per kWh $0.1968 $
2. Off-Peak Per kWh $0.0412 $
b. Energy and demand credit – non-summer season billing months
1. On-Peak (Mon-Fri, 5 pm to 9 pm, excluding holidays) Per kWh $0.1632 $
2. Off-Peak Per kWh $0.0395 $
. . .
(r) Net metering-community solar projects.
. . .
(3) Both the customer's consumption of energy from Fort Collins Utilities and
interest in the production of energy that flows into Fort Collins Utilities'
distribution system shall be measured on a monthly basis. The energy consumed
from Fort Collins Utilities by the customer shall be billed at the applicable
seasonal tiered rate as outlined in Subsections (c) and (d) of this Section. The
method used to measure energy produced and issue credits under this Section
shall be identical for customers participating in third-party administered and City
low-income community solar projects. The energy produced by the customer's
portion of the qualifying facility shall be credited to the customer monthly as
follows:
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1. Distribution facilities credit Per kWh $0.0119
2. Energy and demand credit Per kWh $0.0632
$0.0634
(s) Time of Use (TOU) Pilot Study.
(1) Objective. The City has identified potential benefits available through
time-of-use (TOU) based electric service rates, including encouraging reduced
energy consumption and equitably shifting energy costs to customers who use
more energy. In order to study these benefits, Fort Collins Utilities shall conduct a
temporary pilot project beginning with the billing cycle commencing on or after
October 1, 2015, and concluding after twelve (12) full billing cycles.
(2) Scope. The project shall include six thousand residential energy service
(Schedule R) customers selected at random. Customers selected at random will be
notified and given a one-time opportunity to "opt-out" of participation in the
project. Customers who do not opt-out will be assigned, as determined by the
Executive Director, to one of the two pilot rates described in Subsections (s)(4)
(pilot TOU rate) and (s)(5) (pilot TOU with energy efficiency tier rate), or
monitored on their existing residential energy service tiered rate, as a control
group.
(3) Best-bill guarantee. Customers participating in the pilot project for the full
twelve (12) billing cycle period will be eligible for the following best-bill
guarantee: the total energy costs paid by each customer under either of the pilot
rates for the twelve full billing cycles shall be compared with the energy costs
such customer would have paid under the base residential energy service tiered
rate during the same twelve billing cycles, and each customer shall be reimbursed
(by issuance of a billing credit or otherwise, as determined by the Executive
Director) for the amount by which the total energy costs paid exceed the amount
that would have been due under the base residential energy service tiered rate for
such period. Each customer who pays total energy costs under either of the pilot
rates during the twelve full billing cycles of the project that are less than the
energy costs such customer would have paid under the base residential energy
service tiered rate shall retain those savings.
(4) Pilot TOU rate. Customers assigned to this rate during the pilot study shall
pay monthly rates under this sub-schedule equal to the sum of the following
charges:
a. Fixed Charge Per account $5.07 $
b. Distribution facilities charge Per kWh $0.0238 $
c. Energy and demand charge
1. Summer. During the summer season billing months of May, June, July and August, and
September
(a) On-Peak (Mon-Fri, 2 pm to 7 pm, excluding holidays) Per kWh $0.1968 $
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(b) Off-Peak Per kWh $0.0412 $
2. Non-summer. During the non-summer season billing months of January through April and
October through December.
(a) On-Peak (Mon-Fri, 5 pm to 9 pm, excluding holidays)
(b) Off-Peak
Per kWh $0.1632 $
Per kWh $0.0395 $
d. Payment in lieu of taxes (PILOT) and franchise.
A charge based on all monthly service charges billed pursuant to this Section
6 percent
(5) Pilot TOU with energy efficiency tier rate. Customers assigned to this rate
during the pilot study shall pay monthly rates under this sub-schedule equal to the
sum of the following charges:
a. Fixed Charge Per account $5.07 $
b. Distribution facilities charge Per kWh $0.0194 $
c. Energy and demand charge
1. Summer. During the summer season billing months of May, June, July, August, and
September
(a) On-Peak (Mon-Fri, 2 pm to 7 pm, excluding holidays)
(b) Off-Peak
Per kWh $0.1968 $
Per kWh $0.0412 $
2. Non-summer. During the non-summer season billing months of January through April and
October through December.
(a) On-Peak (Mon-Fri, 5 pm to 9 pm, excluding holidays)
(b) Off-Peak
Per kWh $0.1632 $
Per kWh $0.0395 $
d. Energy efficiency tier charge, per kilowatt hour for total
consumption over 700 kWh in a billing month (regardless of on-peak or
off-peak)
Per kWh $0.0163 $
e. Payment in lieu of taxes (PILOT) and franchise.
A charge based on all monthly service charges billed pursuant to this Section
6 percent
Section 3. That Sections 26-465 (c) through (f), (q), and (r) of the Code of the City of
Fort Collins are hereby amended to read as follows:
Sec. 26-465. Residential demand service, schedule RD.
. . .
(c) Monthly rate. The monthly rates shall be the sum of the following charges:
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(1) Fixed Charge Per account $5.07
$6.94
(2) Demand charge Per kW $2.36
$2.44
(3) Distribution facilities charge Per kWh $0.0211
(4) Energy charge
a. Summer season billing months of June, July and August
b. Non-summer season billing months of January through
May and September through December
Per kWh $0.0435
$0.0443
Per kWh $0.0418
$0.0425
c. The meter reading date shall generally determine the
summer season billing months; however, no customer shall
be billed more than three (3) full billing cycles at the
summer rate.
(5) Payment in lieu of taxes (PILOT) and franchise.
A charge based on all monthly service charges billed pursuant to this Section
6 percent
(d) Renewable resource. Renewable energy resources, including, but not limited to,
energy generated by the power of wind, may be offered on a voluntary basis to customers
at the premium per kilowatt hour set forth in this Subsection (d). The utility may establish
and offer voluntary programs designed to increase and enhance the use of energy
generated by renewable energy resources in support of Council-adopted policy applicable
to the utility.
Per kWh $0.024
$0.025
(e) Excess capacity charge. The monthly capacity charge kilowatt set forth in this
Subsection (e) may be added to the above charges for service to intermittent loads in
accordance with the provisions of the Electric Service Standards.
Per kW $2.00
$2.09
(f) Standby service charges. Standby service, if available, will be provided on an
annual contract basis at a level at least sufficient to meet probable service demand (in
kilowatts) as determined by the customer and approved by the utility according to the
following:
(1) Monthly standby distribution charge:
Contracted standby service, this charge shall be in lieu of the distribution
facilities charge. Per kW
$2.33
$2.11
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. . .
(q) Net metering.
. . .
(5) The customer-generator's consumption of energy from the utility and
production of energy that flows into the utility's distribution system shall be
measured on a monthly basis. The energy consumed from the utility by the
customer-generator shall be billed at the applicable seasonal tiered rate as outlined
in Subsection (c) of this Section. The energy produced by the customer-generator
shall be credited to the customer monthly as follows:
a. Distribution facilities credit Per kWh $0.0238
b. Energy and demand credit Per kWh $0.0632
$0.0634
(r) Net metering-community solar projects.
. . .
(3) Both the customer's consumption of energy from Fort Collins Utilities and
interest in the production of energy that flows into Fort Collins Utilities'
distribution system shall be measured on a monthly basis. The energy consumed
from Fort Collins Utilities by the customer shall be billed at the applicable
seasonal tiered rate as outlined in Subsection (c) of this Section. The method used
to measure energy produced and issue credits under this Section shall be identical
for customers participating in third-party administered and City low-income
community solar projects. The energy produced by the customer's portion of the
qualifying facility shall be credited to the customer monthly as follows:
1. Distribution facilities credit Per kWh $0.0119
2. Energy and demand credit Per kWh $0.0632
$0.0634
Section 4. That Sections 26-465 (c)-(e), (q), and (r) of the Code of the City of Fort
Collins are hereby amended to read as follows:
Sec. 26-466. General service, schedule GS.
. . .
For all metered kilowatts in excess of the contracted amount Per kW $6.99
$6.33
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(c) Monthly rate. The monthly rates for this schedule shall be the sum of the
following charges:
1. Fixed Charge
a. Single-phase, two-hundred-ampere service Per account $ 3.26
$3.60
b. Single-phase, above two-hundred-ampere service Per account $ 9.60
$10.61
c. Three-phase, two-hundred-ampere service Per account $ 4.96
$5.48
d. Three-phase, above two-hundred-ampere service Per account $11.74
$12.98
2. Demand charge
a. Summer season billing months of June, July, and
August
Per kWh $0.0289
$0.0268
b. Non-summer season billing months of January through
May and September through December
Per kWh $0.0156
$0.0164
c. The meter reading date shall generally determine the
summer season billing months; however, no customer
shall be billed more than three (3) full billing cycles at
the summer rate.
3. Distribution facilities charge Per kWh $0.0227
$0.0244
4. Energy charge
a. Summer season billing months of June, July, and
August
Per kWh $0.0435
$0.0443
b. Non-summer season billing months of January through
May and September through December
Per kWh $0.0418
$0.0425
c. The meter reading date shall generally determine the
summer season billing months; however, no customer
shall be billed more than three (3) full billing cycles at
the summer rate.
5. Payment in lieu of taxes (PILOT) and franchise.
A charge based on all monthly service charges billed pursuant to
this Section
6 percent
(d) Renewable resource. Renewable energy resources, including, but not limited to,
energy generated by the power of wind, may be offered on a voluntary basis to customers
at the premium per kilowatt hour set forth in this Subsection (d). The utility may establish
and offer voluntary programs designed to increase and enhance the use of energy
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generated by renewable energy resources in support of Council-adopted policy applicable
to the utility.
Per kWh $0.024
$0.025
(e) Excess capacity charge. The monthly capacity charge per kilowatt set forth in
this Subsection (e) may be added to the above charges for service to intermittent loads in
accordance with the provisions of the Electric Service Standards.
Per kW $2.00
$2.09
. . .
(q) Net metering.
. . .
(5) The customer-generator's consumption of energy from the utility and
production of energy that flows into the utility's distribution system shall be
measured on a monthly basis. The energy consumed from the utility by the
customer-generator shall be billed at the applicable rate as outlined in Subsection
(c) of this Section. The energy produced by the customer-generator shall be
credited to the customer monthly as follows:
a. Summer season energy credit Per kWh $0.0435
$0.0443
(r) Net metering-community solar projects.
. . .
(3) Both the customer's consumption of energy from Fort Collins Utilities and
interest in the production of energy that flows into Fort Collins Utilities'
distribution system shall be measured on a monthly basis. The energy consumed
from Fort Collins Utilities by the customer shall be billed at the applicable
seasonal tiered rate as outlined in Subsection (c) of this Section. The energy
produced by the customer's portion of the qualifying facility shall be credited to
the customer monthly as follows:
1. Distribution facilities credit Per kWh $0.0114
$0.0122
2. Energy and demand credit Per kWh $0.0435
$0.0443
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. . .
Section 5. That Sections 26-467 (c) through (f) and (r) of the Code of the City of Fort
Collins are hereby amended to read as follows:
Sec. 26-467. General service 25, schedule GS25.
. . .
(c) Monthly rate. The monthly rates for this schedule shall be the sum of the
following charges:
1. Fixed Charge
a. Single-phase, two-hundred-ampere service Per account $ 3.26
$3.60
b. Single-phase, above two-hundred-ampere service Per account $ 9.60
$10.61
c. Three-phase, two-hundred-ampere service Per account $ 4.96
$5.48
d. Three-phase, above two-hundred-ampere service Per account $11.74
$12.98
2. Demand charge
a. Summer season billing months of June, July, and
August
Per kW $7.86
$8.28
b. Non-summer season billing months of January through
May and September through December
Per kW $4.57
$4.74
c. The meter reading date shall generally determine the
summer season billing months; however, no customer
shall be billed more than three (3) full billing cycles at
the summer rate.
3. Distribution facilities charge Per kwh $0.0176
$0.0185
4. Energy charge
a. Summer season billing months of June, July, and
August
Per kWh $0.0435
$0.0443
b. Non-summer season billing months of January through
May and September through December
Per kWh $0.0418
$0.0425
c. The meter reading date shall generally determine the
summer season billing months; however, no customer
shall be billed more than three (3) full billing cycles at
the summer rate.
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5. Payment in lieu of taxes (PILOT) and franchise.
A charge based on all monthly service charges billed pursuant to
this Section
6 percent
(d) Renewable resource. Renewable energy resources, including, but not limited to,
energy generated by the power of wind, may be offered on a voluntary basis to customers
at the premium per kilowatt hour set forth in this Subsection (d). The utility may establish
and offer voluntary programs designed to increase and enhance the use of energy
generated by renewable energy resources in support of Council-adopted policy applicable
to the utility.
Per kWh $0.024
$0.025
(e) Excess capacity charge. The monthly capacity charge kilowatt set forth in this
Subsection (e) may be added to the above charges for service to intermittent loads in
accordance with the provisions of the Electric Service Standards.
Per kW $2.00
$2.09
(f) Standby service charges. Standby service, if available, will be provided on an
annual contract basis at a level at least sufficient to meet probable service demand (in
kilowatts) as determined by the customer and approved by the utility according to the
following:
(1) Monthly standby distribution charge
Contracted standby service, this charge shall be in lieu of the distribution
facilities charge. Per kW
$3.82
$3.83
For all metered kilowatts in excess of the contracted amount Per kW $11.45
$11.50
. . .
(r) Net metering.
. . .
(5) The customer-generator's consumption of energy from the utility and
production of energy that flows into the utility's distribution system shall be
measured on a monthly basis. The energy consumed from the utility by the
customer-generator shall be billed at the applicable rate as outlined in Subsection
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(c) of this Section. The energy produced by the customer-generator shall be
credited to the customer monthly as follows:
a. Summer season energy credit Per kWh $0.0435
$0.0443
Section 6. That Sections 26-468 (c) through (g), and (u) of the Code of the City of
Fort Collins are hereby amended to read as follows:
Sec. 26-468. General service 50, schedule GS50.
. . .
(c) Monthly rate. The monthly rates for this schedule shall be the sum of the
following charges:
(1) Fixed Charge Per account
$9.45
$9.08
An additional charge may be assessed if telephone
communication service is not provided by the customer. Per account $40.00
(2) Coincident demand charge
a. summer season billing months of June, July and August Per kW $11.68
b. non-summer season billing months of January through
May and September through December Per kW
$8.15
$8.90
c. The meter reading date shall generally determine the
summer season billing months; however, no customer
shall be billed more than three (3) full billing cycles at
the summer rate.
(3) Distribution facilities charge Per kW $5.90
$6.25
(4) Energy charge
a. Summer season billing months of June, July, and August Per kWh $0.0435
$0.0443
b. Non-summer season billing months of January through
May and September through December
Per kWh $0.0418
$0.0425
c. The meter reading date shall generally determine the
summer season billing months; however, no customer
shall be billed more than three (3) full billing cycles at
the summer rate.
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(5) Payment in lieu of taxes (PILOT) and franchise.
A charge based on all monthly service charges billed pursuant to
this Section
6 percent
(d) Renewable resource. Renewable energy resources, including, but not limited to,
energy generated by the power of wind, may be offered on a voluntary basis to customers
at the premium per kilowatt hour set forth in this Subsection (d). The utility may establish
and offer voluntary programs designed to increase and enhance the use of energy
generated by renewable energy resources in support of Council-adopted policy applicable
to the utility.
Per kWh $0.024
$0.025
(e) Excess capacity charge. The monthly capacity charge per kilowatt set forth in this
Subsection (e) may be added to the above charges for service to intermittent loads in
accordance with the provisions of the Electric Service Standards.
Per kW $2.00
$2.09
(f) Standby service charges. Standby service, if available, will be provided on an
annual contract basis at a level at least sufficient to meet probable service demand (in
kilowatts) as determined by the customer and approved by the utility according to the
following:
(1) Standby distribution charge.
a. Monthly standby distribution charge shall be the sum of the
following charges:
Contracted standby service, this charge shall be in lieu of the distribution
facilities charge. Per kW
$4.72
$4.92
For all metered kilowatts in excess of the contracted amount Per kW $14.16
$14.77
. . .
(g) Excess circuit charge. In the event a utility customer in this rate class desires
excess circuit capacity for the purpose of controlling the available electric capacity of a
backup circuit connection, this service, if available, will be provided on an annual
contract basis at a level at least sufficient to meet probable backup demand (in kilowatts)
as determined by the customer and approved by the utility according to the following:
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(1) Monthly charge shall be the sum of the following charges:
Contracted backup capacity per month Per kW $0.86
$1.01
Metered kilowatts in excess of the contracted amount Per kW $2.58
$3.03
(2) In the event the contractual kilowatt limit is exceeded, a new annual
contract period will automatically begin as of the month the limit is exceeded. The
metered demand in the month of exceedance shall become the minimum
contracted demand level for the excess circuit charge.
. . .
(u) Net metering.
. . .
(5) The customer-generator's consumption of energy from the utility and
production of energy that flows into the utility's distribution system shall be
measured on a monthly basis. The energy consumed from the utility by the
customer-generator shall be billed at the applicable rate as outlined in Subsection
(c) of this Section. The energy produced by the customer-generator shall be
credited to the customer monthly as follows:
a. Summer season energy credit Per kWh $0.0435
$0.0443
Section 7. That Sections 26-469 (c) through (g) and (v) of the Code of the City of
Fort Collins are hereby amended to read as follows:
Sec. 26-469. General service 750, schedule GS750.
. . .
(c) Monthly rate. The monthly rates for this schedule shall be the sum of the
following charges:
(1) Fixed Charge Per account
$15.24
$15.56
a. Additional charge for each additional metering point Per account $9.50
b. An additional charge may be assessed if telephone
communication service is not provided by the customer. Per account $40.00
(2) Coincident demand charge
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a. summer season billing months of June, July and August Per kW $11.51
b. non-summer season billing months of January through
May and September through December Per kW
$8.04
$8.77
c. The meter reading date shall generally determine the
summer season billing months; however, no customer
shall be billed more than three (3) full billing cycles at
the summer rate.
(3) Distribution facilities charge
a. First seven hundred fifty (750) kilowatts Per kW $5.85
$6.00
b. All additional kilowatts Per kW $3.48
$3.55
(4) Energy charge
a. Summer season billing months of June, July, and
August
Per kWh $0.0428
$0.0436
b. Non-summer season billing months of January through
May and September through December
Per kWh $0.0412
$0.0419
c. The meter reading date shall generally determine the
summer season billing months; however, no customer
shall be billed more than three (3) full billing cycles at
the summer rate.
(5) Payment in lieu of taxes (PILOT) and franchise.
A charge based on all monthly service charges billed pursuant to
this Section
6 percent
(d) Renewable resource. Renewable energy resources, including, but not limited to,
energy generated by the power of wind, may be offered on a voluntary basis to customers
at the premium per kilowatt hour set forth in this Subsection (d). The utility may establish
and offer voluntary programs designed to increase and enhance the use of energy
generated by renewable energy resources in support of Council-adopted policy applicable
to the utility.
Per kWh $0.024
$0.025
(e) Excess capacity charge. The monthly capacity charge per kilowatt set forth in this
Subsection (e) may be added to the above charges for service to intermittent loads in
accordance with the provisions of the Electric Service Standards.
Per kW $2.00
$2.09
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(f) Standby service charges. Standby service, if available, will be provided on an
annual contract basis at a level at least sufficient to meet probable service demand (in
kilowatts) as determined by the customer and approved by the utility according to the
following:
(1) Standby distribution charge.
a. Monthly standby distribution charges shall be paid in the following
amounts
Contracted standby service, this charge shall be in lieu of the distribution
facilities charge. Per kW
$3.52
$3.41
For all metered kilowatts in excess of the contracted amount Per kW $10.56
$10.24
. . .
(g) Excess circuit charge. In the event a utility customer in this rate class desires
excess circuit capacity for the purpose of controlling the available electric capacity of a
backup circuit connection, this service, if available, will be provided on an annual
contract basis at a level at least sufficient to meet probable backup demand (in kilowatts)
as determined by the customer and approved by the utility at the following:
(1) Monthly charge.
. . .
(v) Net metering.
. . .
(5) The customer-generator's consumption of energy from the utility and
production of energy that flows into the utility's distribution system shall be
measured on a monthly basis. The energy consumed from the utility by the
customer-generator shall be billed at the applicable rate as outlined in Subsection
(c) of this Section. The energy produced by the customer-generator shall be
credited to the customer monthly as follows:
a. Summer season energy credit Per kWh $0.0428
$0.0436
Contracted backup capacity per month Per kW $0.64
$0.70
Metered kilowatts in excess of the contracted amount Per kW $1.92
$2.10
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Section 8. That Sections 26-470 (c) through (e), and (s) of the Code of the City of
Fort Collins are hereby amended to read as follows:
Sec. 26-470. Substation service, schedule SS.
. . .
(c) Monthly rate. The monthly rates for this schedule shall be the sum of the
following charges:
(1) Fixed Charge Per account
$39.47
$35.38
(2) Coincident demand charge
a. summer season billing months of June, July and August Per kW $11.33
b. non-summer season billing months of January through
May and September through December Per kW
$7.91
$8.64
c. The meter reading date shall generally determine the
summer season billing months; however, no customer
shall be billed more than three (3) full billing cycles at
the summer rate.
(3) Distribution facilities charge Per kW $2.50
$2.87
(4) Energy charge
a. Summer season billing months of June, July, and
August
Per kWh $0.0422
$0.0430
b. Non-summer season billing months of January through
May and September through December
Per kWh $0.0405
$0.0412
c. The meter reading date shall generally determine the
summer season billing months; however, no customer
shall be billed more than three (3) full billing cycles at
the summer rate.
(5) Payment in lieu of taxes (PILOT) and franchise.
A charge based on all monthly service charges billed pursuant to
this Section
6 percent
(d) Renewable resource. Renewable energy resources, including, but not limited to,
energy generated by the power of wind, may be offered on a voluntary basis to customers
at a premium per kilowatt hour. The utility may establish and offer voluntary programs
designed to increase and enhance the use of energy generated by renewable energy
resources in support of Council-adopted policy applicable to the utility.
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Per kWh $0.024
$0.025
(e) Standby service charges. Standby service, if available, will be provided on an
annual contract basis at a level at least sufficient to meet probable service demand (in
kilowatts) as determined by the customer and approved by the utility at the following
rates:
(1) Standby distribution charge.
a. Monthly standby distribution charge:
Contracted standby service, this charge shall be in lieu of the
distribution facilities charge. Per kW
$2.22
$2.55
For all metered kilowatts in excess of the contracted amount Per kW $6.66
$7.65
. . .
(s) Net metering.
. . .
(5) The customer-generator's consumption of energy from the utility and
production of energy that flows into the utility's distribution system shall be
measured on a monthly basis. The energy consumed from the utility by the
customer-generator shall be billed at the applicable rate as outlined in Subsection
(c) of this Section. The energy produced by the customer-generator shall be
credited to the customer monthly as follows:
a. Summer season energy credit Per kWh $0.0422
$0.0430
Section 9. That the amendments herein are effective and shall go into effect as
follows:
a. Amended GS50 & GS750 schedule rates shall apply to all electricity used
on or after January 1, 2017;
b. All other amended schedule rates shall apply to all bills issued on the basis
of meter readings on or after January 1, 2017.
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Introduced, considered favorably on first reading, and ordered published this 1st day of
November, A.D. 2016, and to be presented for final passage on the 15th day of November, A.D.
2016.
__________________________________
Mayor
ATTEST:
_______________________________
City Clerk
Passed and adopted on final reading on the 15th day of November, A.D. 2016.
__________________________________
Mayor
ATTEST:
_______________________________
City Clerk
OPTION NOT ADOPTED
ON FIRST READING
-1-
OPTION 1 (3% increase)
ORDINANCE NO. 123, 2016
OF THE COUNCIL OF THE CITY OF FORT COLLINS
AMENDING CHAPTER 26 OF THE CODE OF THE CITY OF FORT
COLLINS TO REVISE WATER RATES, FEES, AND CHARGES
WHEREAS, the City Council is empowered and directed by Article XII, Section 6 of the
Charter of the City of Fort Collins, to by ordinance from time to time fix, establish, maintain and
provide for the collection of such rates, fees or charges for utility services furnished by the City
as will produce revenues sufficient to pay the costs, expenses, and other obligations as set forth
therein; and
WHEREAS, the rates, fees or charges for utility services set forth herein are necessary to
produce sufficient revenues to provide the utility services described herein; and
WHEREAS, the revenue from the rates, fees or charges for utility services set forth
herein shall be used to defray the costs of providing such utility services as required by the
Charter and the City Code; and
WHEREAS, Article III, Chapter 26 of the City Code establishes the water utility as a
utility service furnished by and an enterprise of the City; and
WHEREAS, City Code Sections 26-126, 26-127 and 26-129 concern various water-
related rates, fees, and charges; and
WHEREAS, City Code Section 26-118 requires that the City Manager to analyze the
operating and financial records of the utility during each calendar year and recommend to the
City Council user rates or adjustments to be in effect for the following year; and
WHEREAS, the City Manager and City staff have recommended to the City Council
adjustment of the water-related rates, fees, and charges as set forth herein to be effective January
1, 2017; and
WHEREAS, the rate increase for water set forth herein is 3% for all customer classes;
and
WHEREAS, the Water Board considered the proposed water-related rates, fees, and
charges adjustments for 2017 at its meeting on October 20, 2016 and recommended approval of
the proposed adjustments by a unanimous vote; and
WHEREAS, based on the foregoing, City Council desires to amend Chapter 26 of the
City Code to adjust the scope and rate of the water-related rates, fees, and charges as set forth
herein.
OPTION NOT ADOPTED
ON FIRST READING
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NOW, THEREFORE, BE IT ORDAINED BY THE COUNCIL OF THE CITY OF
FORT COLLINS as follows:
Section 1. That the City Council hereby makes any and all determinations and
findings contained in the recitals set forth above.
Section 2. That Section 26-126 of the Code of the City of Fort Collins is hereby
amended to read as follows:
Sec. 26-126. - Schedule A, flat rates for unmetered construction water use.
For residential and nonresidential premises under construction with a planned meter size
greater than one (1) inch, no flat unmetered water service will be provided. For
residential and nonresidential premises under construction with a planned meter size of
one (1) inch or less, the following flat rates will apply per month until the permanent
meter is set:
¾-inch construction service, flat charge per month $26.91 $27.72
1-inch construction service, flat charge per month 51.31 $52.85
Section 3. That Section 26-127 of the Code of the City of Fort Collins is hereby
amended to read as follows:
Sec. 26-127. - Schedule B, meter rates.
(a) Residential rates.
(1) Residential customers with one (1) dwelling unit shall pay the sum of the
following changes:
a. Base monthly charge for residential customers with one (1) dwelling unit $15.41 $15.87
b. Quantity monthly charge for residential customers with one (1) dwelling
unit
Tier 1 - For the first seven thousand (7,000) gallons used per month, per
one thousand (1,000) gallons
$2.386 $2.458
Tier 2 - For the next six thousand (6,000) gallons used per month, per one
thousand (1,000) gallons
$2.742 $2.824
Tier 3 - For all additional gallons used per month, per one thousand
(1,000) gallons
$3.154 $3.249
(2) Residential customers with two (2) dwelling units shall pay the sum of the
following charges:
a. Base monthly charge for residential customers with two (2) dwelling units $16.31 $16.80
OPTION NOT ADOPTED
ON FIRST READING
-3-
b. Quantity monthly charge for residential customers with two (2) dwelling
units
Tier 1 - For the first nine thousand (9,000) gallons used per month, per one
thousand (1,000) gallons
$2.071 $2.133
Tier 2 - For the next four thousand (4,000) gallons used per month, per
one thousand (1,000) gallons
$2.380 $2.451
Tier 3 - For all additional gallons used per month, per one thousand
(1,000) gallons
$2.739 $2.821
(3) Residential customers with more than two (2) dwelling units shall pay the
sum of the following charges:
a. Base monthly charge for residential customers with more than two (2)
dwelling units
First dwelling unit $11.72 $12.07
Second and each additional dwelling unit $3.90 $4.02
b. Quantity monthly charge for residential customers with more than two
(2) dwelling units
Winter - per one thousand (1,000) gallons used in the winter season months
of November through April
$1.703 $1.754
Summer - per one thousand (1,000) gallons used in the summer season
months of May through October
$2.129 $2.193
The meter reading date shall generally determine the seasonal monthly
quantity charge; however, no customer shall be billed more than six (6) full
billing cycles at the summer quantity charge.
(b) Nonresidential rates.
(1) Base charge. Nonresidential, except for special users as described in
Subsection 26-127(c) below, customers shall pay a base monthly charge based on
meter size as follows:
Meter Size (inches) Monthly Base Charge
¾ $13.63 $14.04
1 38.03 $39.17
1½ 103.41 $106.51
2 155.85 $160.53
3 237.70 $244.83
4 373.17 $384.37
6 723.91 $745.63
8 1,278.85 $1317.22
OPTION NOT ADOPTED
ON FIRST READING
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(2) Quantity charges. Nonresidential customers shall pay monthly charges as
follows:
Winter - per one thousand (1,000) gallons used in the winter season
months of November through April $1.897 $1.954
Summer - per one thousand (1,000) gallons used in the summer season
months of May through October $2.370 $2.441
The meter reading date shall generally determine the seasonal monthly
quantity charge; however, no customer shall be billed more than six (6)
full billing cycles at the summer quantity charge.
(3) Charges for excess use. Nonresidential customers shall also pay monthly
water use charges in excess of the amounts specified in the following table:
Winter - per one thousand (1,000) gallons used in the winter
season months of November through April
$2.725 $2.807
Summer - per one thousand (1,000) gallons used in the summer
season months of May through October
$3.408 $3.510
The meter reading date shall generally determine the seasonal
monthly quantity charge; however, no customer shall be billed
more than six (6) full billing cycles at the summer quantity
charge.
Meter Size (inches)
Specified Amount
(gallons per month)
¾ 100,000
1 300,000
1½ 625,000
2 1,200,000
3 1,400,000
4 2,500,000
(c) High volume industrial rates. High volume industrial rates apply to any customer
with an average daily demand in excess of two million (2,000,000) gallons per day. The
specific rate for any qualifying customer shall be based upon the applicable peaking
factor for that customer as follows:
Peaking Factor
Monthly Charge per
Thousand Gallons
1.00—1.09 $1.490 $1.53
1.10—1.19 1.540 $1.59
OPTION NOT ADOPTED
ON FIRST READING
-5-
1.20—1.29 1.590 $1.64
1.30—1.39 1.640 $1.69
1.40—1.49 1.690 $1.74
1.50—1.59 1.740 $1.79
1.60—1.69 1.790 $1.84
1.70—1.79 1.840 $1.90
1.80—1.89 1.890 $1.95
1.90—1.99 1.950 $2.01
> 2.00 2.000 $2.06
. . .
Section 4. That the modifications set forth above shall be effective for meter readings
on or after January 1, 2017, and in the case of fees not based on meter readings, shall be effective
for all fees paid on or after January 1, 2017.
Introduced, considered favorably on first reading, and ordered published this 1st day of
November, A.D. 2016, and to be presented for final passage on the 15th day of November, A.D.
2016.
__________________________________
Mayor
ATTEST:
_______________________________
City Clerk
Passed and adopted on final reading on the 15th day of November, A.D. 2016.
__________________________________
Mayor
ATTEST:
_______________________________
City Clerk
OPTION NOT ADOPTED
ON FIRST READING
-1-
OPTION 2 (3% increase)
ORDINANCE NO. 125, 2016
OF THE COUNCIL OF THE CITY OF FORT COLLINS
AMENDING CHAPTER 26 OF THE CODE OF THE CITY OF FORT
COLLINS TO REVISE STORMWATER RATES, FEES, AND CHARGES
WHEREAS, the City Council is empowered and directed by Article XII, Section 6 of the
City Charter, to by ordinance from time to time fix, establish, maintain and provide for the
collection of such rates, fees or charges for utility services furnished by the City as will produce
revenues sufficient to pay the costs, expenses, and other obligations as set forth therein; and
WHEREAS, the rates, fees or charges for utility services set forth herein are necessary to
produce sufficient revenues to provide the utility services described herein; and
WHEREAS, the revenue from the rates, fees or charges for utility services set forth
herein shall be used to defray the costs of providing such utility services as required by the
Charter and the City Code; and
WHEREAS, Article VII, Chapter 26 of the City Code establishes the stormwater utility
as a utility service furnished by and an enterprise of the City; and
WHEREAS, City Council has adopted stormwater basin and City-wide master plans
recommending stormwater facilities necessary to provide for proper drainage and control of
flood and surface waters within the City; and
WHEREAS, in 1998, City Council adopted Ordinance No. 168, 1998, determining that
all lands within the City benefit by the installation of such stormwater facilities; and
WHEREAS, City Code Section 26-513 imposes stormwater utility fees on all parcels of
land within the City to pay for the operation, maintenance, administration and routine functions
of the existing and future City stormwater facilities established within the City; and
WHEREAS, City Code Section 26-514 sets forth the manner in which stormwater utility
fees are to be determined; and
WHEREAS, the proposed stormwater utility fee adjustment for 2017 reflects an increase
of approximately 3%; and
WHEREAS, the Water Board considered the proposed stormwater utility fee adjustments
for 2017 at its meeting on October 20, 2016, and recommended approval of the proposed
adjustments; and
WHEREAS, based on the foregoing, City Council desires to amend Chapter 26 of the
City Code to adjust the scope and rate of the stormwater utility fee as set forth herein.
OPTION NOT ADOPTED
ON FIRST READING
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NOW, THEREFORE, BE IT ORDAINED BY THE COUNCIL OF THE CITY OF
FORT COLLINS as follows:
Section 1. That the City Council hereby makes and adopts the determinations and
findings contained in the recitals set forth above.
Section 2. That Section 26-514(a)(3) of the Code of the City of Fort Collins is hereby
amended to read as follows:
Sec. 26-514. - Determination of stormwater utility fee.
(a) The stormwater utility fee shall be determined as set forth in this Section, and shall be
based upon the area of each lot or parcel of land and the runoff coefficient of the lot or parcel.
For the purposes of this Section, the total lot or parcel area shall include both the actual square
footage of the lot or parcel and the square footage of open space and common areas allocated to
such lot as provided in Paragraph (4) of this Subsection. The stormwater utility fee shall recover
the costs of both operations and maintenance and a portion of capital improvements. The
Utilities Executive Director shall determine the rates that shall apply to each specific lot or parcel
of land within the guidelines herein set forth and shall establish the utility fee in accordance with
the rate together with the other factors set forth as follows:
. . .
(3) The base rate for the stormwater utility fee shall be $0.00414540.0042697 per
square foot per month for all areas of the City.
. . .
Section 3. That the modifications set forth above shall be effective for all fees
accruing on or after January 1, 2017.
Introduced, considered favorably on first reading, and ordered published this 1st day of
November, A.D. 2016, and to be presented for final passage on the 15th day of November, A.D.
2016.
__________________________________
Mayor
ATTEST:
_______________________________
City Clerk
OPTION NOT ADOPTED
ON FIRST READING
-3-
Passed and adopted on final reading on the 15th day of November, A.D. 2016.
__________________________________
Mayor
ATTEST:
_______________________________
City Clerk
-1-
ORDINANCE NO. 122, 2016
OF THE COUNCIL OF THE CITY OF FORT COLLINS
AMENDING CHAPTER 26 OF THE CODE OF THE CITY OF FORT
COLLINS TO REVISE ELECTRIC RATES, FEES, AND CHARGES
WHEREAS, the City Council is empowered and directed by Article XII, Section 6, of the
City Charter to fix, establish, maintain and provide for the collection of such rates, fees or
charges for utility services furnished by the City as will produce revenues sufficient to pay the
costs, expenses and other obligations of the electric utility, as set forth therein; and
WHEREAS, the rates, fees or charges for utility services set forth herein are necessary to
produce sufficient revenues to provide the utility services described herein; and
WHEREAS, the revenue from the rates, fees or charges for utility services set forth
herein shall be used to defray the costs of providing such utility services as required by the
Charter and the City Code; and
WHEREAS, the City purchases bulk wholesale electric power from Platte River Power
Authority (“PRPA”) pursuant to an Amended Contract for Supply of Electric Power and Energy,
dated September 1, 2010; and
WHEREAS, PRPA costs are increasing due to reduced wholesale market prices and
surplus sales, increased costs for coal, and increased operating costs for aging plants; and
WHEREAS, PRPA will increase the City’s wholesale cost of power approximately 3.0%
in 2017; and
WHEREAS, the increased wholesale power cost will require an average 2.2% rate
increase and increased local distribution costs will require an additional average 1.25% rate
increase, for a total City electric rates increase in 2017 of 3.45% in order to remain consistent
with Article XII, Section 6, of the City Charter; and
WHEREAS, the proposed rate increase will vary by customer class based on the cost of
service to each class; and
WHEREAS, in addition to adjusting the electric rates in the City Code, Utilities staff has
identified formatting and maintenance updates to Chapter 26 of the City Code necessary to
improve the clarity with which electric rates are stated; and
WHEREAS, the Energy Board considered the proposed electric rates, fees, and charges,
and language clarifications for 2017 at its October 6, 2016 regular meeting and provided a
recommendation of approval to City Council; and
WHEREAS, the City Manager and staff have recommended to the City Council the
following electric rate adjustments and City Code rate language clarifications for all electricity
used by GS50 and GS750 rate class customers on or after January 1, 2017, and for all other
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customer classes for all billings issued with meter readings on or after January 1, 2017; and
WHEREAS, based on the foregoing, it is the desire of the City Council to amend Chapter
26 of the City Code to revise the electric rates, fees and charges.
NOW, THEREFORE, BE IT ORDAINED BY THE COUNCIL OF THE CITY OF
FORT COLLINS as follows:
Section 1. That the City Council hereby makes and adopts the determinations and
findings contained in the recitals set forth above.
Section 2. That Sections 26-464 (c) through (f), and (p), (r) and (s) of the Code of the
City of Fort Collins are hereby amended to read as follows:
Sec. 26-464. Residential energy service, schedule R.
. . .
(c) Monthly rate. The monthly rates for this schedule shall be the sum of the
following charges:
(1) Fixed Charge Per account $5.79
(2) Distribution facilities charge Per kWh $0.0256
(3) Energy and demand charge
a. Summer. During the summer season billing months of June, July and August, with the
summer season billing month determined by the month the meter is read, and provided that no
customer shall be billed more than three (3) full billing cycles at the summer rate.
1. Tier 1 - for the first five hundred (500) kilowatt hours
per month
2. Tier 2 - for the next five hundred (500) kilowatt hours
per month
3. Tier 3 - for all additional kilowatt hours per month
Per kWh $0.0634
Per kWh $0.0807
Per kWh $0.1150
b. Non-summer. During the non-summer season billing months of January through May
and September through December.
1. Tier 1 - for the first five hundred (500) kilowatt hours
per month, per kWh
2. Tier 2 - for the next five hundred (500) kilowatt hours
per month, per kWh
3. Tier 3 - for all additional kilowatt hours per month, per
kWh
Per kWh $0.0583
Per kWh $0.0625
Per kWh $0.0719
(4) Payment in lieu of taxes (PILOT) and franchise.
A charge based on all monthly service charges billed pursuant to this Section
6 percent
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(d) Medical assistance program.
. . .
(3) The discounted monthly rates for customers with electrical durable
medical equipment only shall be the sum of the following charges:
a. Fixed Charge Per account $5.79
b. Distribution facilities charge Per kWh $0.0256
c. Energy and demand charge
1. Summer. During the summer season billing months of June, July and August, with the
summer season billing month determined by the month the meter is read, and provided
that no customer shall be billed more than three (3) full billing cycles at the summer
rate.
(a) Tier 1 - for the first five hundred (500) kilowatt hours
per month
(b) Tier 2 - for the next five hundred (500) kilowatt hours
per month
(c) Tier 3 - for all additional kilowatt hours per month
Per kWh $0.0358
Per kWh $0.0807
Per kWh $0.1150
2. Non-summer. During the non-summer season billing months of January through May
and September through December.
(a) Tier 1 - for the first five hundred (500) kilowatt hours
per month, per kWh
(b) Tier 2 - for the next five hundred (500) kilowatt hours
per month, per kWh
(c) Tier 3 - for all additional kilowatt hours per month, per
kWh
Per kWh $0.0318
Per kWh
$0.0625
Per kWh $0.0719
d. Payment in lieu of taxes (PILOT) and franchise.
A charge based on all monthly service charges billed pursuant to this Section
6 percent
(4) The discounted monthly rates for customers with medical needs requiring
air conditioning only shall be the sum of the following charges:
a. Fixed Charge Per account $5.79
b. Distribution facilities charge Per kWh $0.0256
c. Energy and demand charge
1. Summer. During the summer season billing months of June, July and August, with
the summer season billing month determined by the month the meter is read, and
provided that no customer shall be billed more than three (3) full billing cycles at
the summer rate.
-4-
(a) Tier 1 - for the first five hundred (500) kilowatt hours
per month
(b) Tier 2 - for the next five hundred (500) kilowatt hours
per month
(c) Tier 3 - for all additional kilowatt hours per month
Per kWh $0.0351
Per kWh $0.0446
Per kWh $0.1150
2. Non-summer. During the non-summer season billing months of January through
May and September through December.
(a) Tier 1 - for the first five hundred (500) kilowatt hours
per month, per kWh
(b) Tier 2 - for the next five hundred (500) kilowatt hours
per month, per kWh
(c) Tier 3 - for all additional kilowatt hours per month, per
kWh
Per kWh $0.0583
Per kWh
$0.0625
Per kWh $0.0719
d. Payment in lieu of taxes (PILOT) and franchise.
A charge of all monthly service charges billed pursuant to this Section
6 percent
(5) The discounted monthly rates for customers with electrical durable
medical equipment and medical needs requiring air conditioning shall be the sum
of the following charges:
a. Fixed Charge Per account $5.79
b. Distribution facilities charge Per kWh $0.0256
c. Energy and demand charge
1. Summer. During the summer season billing months of June, July and August, with
the summer season billing month determined by the month the meter is read, and
provided that no customer shall be billed more than three (3) full billing cycles at
the summer rate.
(a) Tier 1 - for the first five hundred (500) kilowatt hours
per month
(b) Tier 2 - for the next five hundred (500) kilowatt hours
per month
(c) Tier 3 - for all additional kilowatt hours per month
Per kWh $0.0229
Per kWh $0.0292
Per kWh $0.1150
2. Non-summer. During the non-summer season billing months of January through
May and September through December.
(a) Tier 1 - for the first five hundred (500) kilowatt hours
per month, per kWh
(b) Tier 2 - for the next five hundred (500) kilowatt hours
per month, per kWh
(c) Tier 3 - for all additional kilowatt hours per month, per
kWh
Per kWh $0.0318
Per kWh
$0.0625
Per kWh $0.0719
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d. Payment in lieu of taxes (PILOT) and franchise.
A charge based on all monthly service charges billed pursuant to this Section
6 percent
. . .
(e) Renewable resource. Renewable energy resources, including, but not limited to,
energy generated by the power of wind, may be offered on a voluntary basis to customers
at the premium per kilowatt hour set forth in this Subsection (e). The utility may establish
and offer voluntary programs designed to increase and enhance the use of energy
generated by renewable energy resources in support of Council-adopted policy applicable
to the utility.
Per kWh $0.025
(f) Excess capacity charge. The monthly capacity charge kilowatt set forth in this
Subsection (f) may be added to the above charges for service to intermittent loads in
accordance with the provisions of the Electric Service Standards.
Per kW $2.09
. . .
(p) Net metering.
…
(5) The customer-generator's consumption of energy from the utility and
production of energy that flows into the utility's distribution system shall be
measured on a monthly basis. The energy consumed from the utility by the
customer-generator shall be billed at the applicable seasonal tiered rate as outlined
in Subsection (c) of this Section. The energy produced by the customer-generator
shall be credited to the customer monthly as follows:
a. Distribution facilities credit Per kWh $0.0256
b. Energy and demand credit Per kWh $0.0634
. . .
(r) Net metering—community solar projects.
. . .
(3) Both the customer’s consumption of energy from Fort Collins Utilities and
interest in the production of energy that flows into Fort Collins Utilities'
-6-
distribution system shall be measured on a monthly basis. The energy consumed
from Fort Collins Utilities by the customer shall be billed at the applicable
seasonal tiered rate as outlined in Subsections (c) and (d) of this Section. The
method used to measure energy produced and issue credits under this Section
shall be identical for customers participating in third-party administered and City
low-income community solar projects. The energy produced by the customer's
portion of the qualifying facility shall be credited to the customer monthly as
follows:
1. Distribution facilities credit Per kWh $0.0128
2. Energy and demand credit Per kWh $0.0634
Section 3. That Sections 26-465 (c) through (f), and (q), and (r) of the Code of the
City of Fort Collins are hereby amended to read as follows:
Sec. 26-465. Residential demand service, schedule RD.
. . .
(c) Monthly rate. The monthly rates shall be the sum of the following charges:
(1) Fixed Charge Per account $5.79
(2) Demand charge Per kW $2.44
(3) Distribution facilities charge Per kWh $0.0228
(4) Energy charge
a. Summer season billing months of June, July and August
b. Non-summer season billing months of January through May
and September through December
Per kWh $0.0443
Per kWh $0.0425
c. The meter reading date shall generally determine the summer
season billing months; however, no customer shall be billed
more than three (3) full billing cycles at the summer rate.
(5) Payment in lieu of taxes (PILOT) and franchise.
A charge based on all monthly service charges billed pursuant to this Section
6 percent
(d) Renewable resource. Renewable energy resources, including, but not limited to,
energy generated by the power of wind, may be offered on a voluntary basis to customers
at the premium per kilowatt hour set forth in this Subsection (d). The utility may establish
and offer voluntary programs designed to increase and enhance the use of energy
generated by renewable energy resources in support of Council-adopted policy applicable
to the utility.
-7-
Per kWh $0.025
(e) Excess capacity charge. The monthly capacity charge kilowatt set forth in this
Subsection (e) may be added to the above charges for service to intermittent loads in
accordance with the provisions of the Electric Service Standards.
Per kW $2.09
(f) Standby service charges. Standby service, if available, will be provided on an
annual contract basis at a level at least sufficient to meet probable service demand (in
kilowatts) as determined by the customer and approved by the utility according to the
following:
(1) Monthly standby distribution charge:
. . .
(q) Net metering.
. . .
(5) The customer-generator's consumption of energy from the utility and
production of energy that flows into the utility's distribution system shall be
measured on a monthly basis. The energy consumed from the utility by the
customer-generator shall be billed at the applicable seasonal tiered rate as outlined
in Subsection (c) of this Section. The energy produced by the customer-generator
shall be credited to the customer monthly as follows:
a. Distribution facilities credit Per kWh $0.0256
b. Energy and demand credit Per kWh $0.0634
(r) Net metering-community solar projects.
. . .
(3) Both the customer's consumption of energy from Fort Collins Utilities and
interest in the production of energy that flows into Fort Collins Utilities'
distribution system shall be measured on a monthly basis. The energy consumed
from Fort Collins Utilities by the customer shall be billed at the applicable
seasonal tiered rate as outlined in Subsection (c) of this Section. The method used
Contracted standby service, this charge shall be in lieu
of the distribution facilities charge.
Per kW $2.11
For all metered kilowatts in excess of the contracted
amount
Per kW $6.33
-8-
to measure energy produced and issue credits under this Section shall be identical
for customers participating in third-party administered and City low-income
community solar projects. The energy produced by the customer's portion of the
qualifying facility shall be credited to the customer monthly as follows:
1. Distribution facilities credit Per kWh $0.0128
2. Energy and demand credit Per kWh $0.0634
Section 4. That Sections 26-466 (c) through (e), (q), and (r) of the Code of the City
of Fort Collins are hereby amended to read as follows:
Sec. 26-466. General service, schedule GS.
. . .
(c) Monthly rate. The monthly rates for this schedule shall be the sum of the
following charges:
1. Fixed Charge
a. Single-phase, two-hundred-ampere service Per account $3.60
b. Single-phase, above two-hundred-ampere service Per account $10.61
c. Three-phase, two-hundred-ampere service Per account $5.48
d. Three-phase, above two-hundred-ampere service Per account $12.98
2. Demand charge
a. Summer season billing months of June, July, and August Per kWh $0.0268
b. Non-summer season billing months of January through May
and September through December
Per kWh $0.0164
c. The meter reading date shall generally determine the
summer season billing months; however, no customer shall
be billed more than three (3) full billing cycles at the
summer rate.
3. Distribution facilities charge Per kWh $0.0244
4. Energy charge
a. Summer season billing months of June, July, and August Per kWh $0.0443
b. Non-summer season billing months of January through May
and September through December
Per kWh $0.0425
c. The meter reading date shall generally determine the
summer season billing months; however, no customer shall
be billed more than three (3) full billing cycles at the
summer rate.
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5. Payment in lieu of taxes (PILOT) and franchise.
A charge based on all monthly service charges billed pursuant to this
Section
6 percent
(d) Renewable resource. Renewable energy resources, including, but not limited to,
energy generated by the power of wind, may be offered on a voluntary basis to customers
at the premium per kilowatt hour set forth in this Subsection (d). The utility may establish
and offer voluntary programs designed to increase and enhance the use of energy
generated by renewable energy resources in support of Council-adopted policy applicable
to the utility.
Per kWh $0.025
(e) Excess capacity charge. The monthly capacity charge per kilowatt set forth in
this Subsection (e) may be added to the above charges for service to intermittent loads in
accordance with the provisions of the Electric Service Standards.
Per kW $2.09
. . .
(q) Net metering.
. . .
(5) The customer-generator's consumption of energy from the utility and
production of energy that flows into the utility's distribution system shall be
measured on a monthly basis. The energy consumed from the utility by the
customer-generator shall be billed at the applicable rate as outlined in Subsection
(c) of this Section. The energy produced by the customer-generator shall be
credited to the customer monthly as follows:
a. Summer season energy credit Per kWh $0.0443
(r) Net metering-community solar projects.
. . .
(3) Both the customer's consumption of energy from Fort Collins Utilities and
interest in the production of energy that flows into Fort Collins Utilities'
distribution system shall be measured on a monthly basis. The energy consumed
from Fort Collins Utilities by the customer shall be billed at the applicable
seasonal tiered rate as outlined in Subsection (c) of this Section. The energy
produced by the customer's portion of the qualifying facility shall be credited to
-10-
the customer monthly as follows:
1. Distribution facilities credit Per kWh $0.0122
2. Energy and demand credit Per kWh $0.0443
. . .
Section 5. That Sections 26-467 (c) through (f) and (r) of the Code of the City of Fort
Collins are hereby amended to read as follows:
Sec. 26-467. General service 25, schedule GS25.
. . .
(c) Monthly rate. The monthly rates for this schedule shall be the sum of the
following charges:
1. Fixed Charge
a. Single-phase, two-hundred-ampere service Per account $3.60
b. Single-phase, above two-hundred-ampere service Per account $10.61
c. Three-phase, two-hundred-ampere service Per account $5.48
d. Three-phase, above two-hundred-ampere service Per account $12.98
2. Demand charge
a. Summer season billing months of June, July, and August Per kW $8.28
b. Non-summer season billing months of January through
May and September through December
Per kW $4.74
c. The meter reading date shall generally determine the
summer season billing months; however, no customer
shall be billed more than three (3) full billing cycles at
the summer rate.
3. Distribution facilities charge Per kwh $0.0185
4. Energy charge
a. Summer season billing months of June, July, and August Per kWh $0.0443
b. Non-summer season billing months of January through
May and September through December
Per kWh $0.0425
c. The meter reading date shall generally determine the
summer season billing months; however, no customer
shall be billed more than three (3) full billing cycles at
the summer rate.
5. Payment in lieu of taxes (PILOT) and franchise.
A charge based on all monthly service charges billed pursuant to this
6 percent
-11-
Section
(d) Renewable resource. Renewable energy resources, including, but not limited to,
energy generated by the power of wind, may be offered on a voluntary basis to customers
at the premium per kilowatt hour set forth in this Subsection (d). The utility may establish
and offer voluntary programs designed to increase and enhance the use of energy
generated by renewable energy resources in support of Council-adopted policy applicable
to the utility.
Per kWh $0.025
(e) Excess capacity charge. The monthly capacity charge kilowatt set forth in this
Subsection (e) may be added to the above charges for service to intermittent loads in
accordance with the provisions of the Electric Service Standards.
Per kW $2.09
(f) Standby service charges. Standby service, if available, will be provided on an
annual contract basis at a level at least sufficient to meet probable service demand (in
kilowatts) as determined by the customer and approved by the utility according to the
following:
(1) Monthly standby distribution charge
Contracted standby service, this charge shall be in lieu of the distribution
facilities charge.
Per kW $3.83
For all metered kilowatts in excess of the contracted amount Per kW $11.50
. . .
(r) Net metering.
. . .
(5) The customer-generator's consumption of energy from the utility and
production of energy that flows into the utility's distribution system shall be
measured on a monthly basis. The energy consumed from the utility by the
customer-generator shall be billed at the applicable rate as outlined in Subsection
(c) of this Section. The energy produced by the customer-generator shall be
credited to the customer monthly as follows:
a. Summer season energy credit Per kWh $0.0443
. . .
-12-
Section 6. That Sections 26-468 (c) through (g), and (u) of the Code of the City of
Fort Collins are hereby amended to read as follows:
Sec. 26-468. General service 50, schedule GS50.
. . .
(c) Monthly rate. The monthly rates for this schedule shall be the sum of the
following charges:
(1) Fixed Charge Per account $9.08
An additional charge may be assessed if telephone communication
service is not provided by the customer.
Per account $40.00
(2) Coincident demand charge
a. summer season billing months of June, July and August Per kW $11.68
b. non-summer season billing months of January through
May and September through December
Per kW $8.90
c. The meter reading date shall generally determine the
summer season billing months; however, no customer
shall be billed more than three (3) full billing cycles at
the summer rate.
(3) Distribution facilities charge Per kW $6.25
(4) Energy charge
a. Summer season billing months of June, July, and August Per kWh $0.0443
b. Non-summer season billing months of January through
May and September through December
Per kWh $0.0425
c. The meter reading date shall generally determine the
summer season billing months; however, no customer
shall be billed more than three (3) full billing cycles at
the summer rate.
(5) Payment in lieu of taxes (PILOT) and franchise.
A charge based on all monthly service charges billed pursuant to this
Section
6 percent
(d) Renewable resource. Renewable energy resources, including, but not limited to,
energy generated by the power of wind, may be offered on a voluntary basis to customers
at the premium per kilowatt hour set forth in this Subsection (d). The utility may establish
and offer voluntary programs designed to increase and enhance the use of energy
generated by renewable energy resources in support of Council-adopted policy applicable
to the utility.
-13-
Per kWh $0.025
(e) Excess capacity charge. The monthly capacity charge per kilowatt set forth in this
Subsection (e) may be added to the above charges for service to intermittent loads in
accordance with the provisions of the Electric Service Standards.
Per kW $2.09
(f) Standby service charges. Standby service, if available, will be provided on an
annual contract basis at a level at least sufficient to meet probable service demand (in
kilowatts) as determined by the customer and approved by the utility according to the
following:
(1) Standby distribution charge.
a. Monthly standby distribution charge shall be the sum of the
following charges:
Contracted standby service, this charge shall be in lieu of the distribution
facilities charge.
Per kW $4.92
For all metered kilowatts in excess of the contracted amount Per kW $14.77
. . .
(g) Excess circuit charge. In the event a utility customer in this rate class desires
excess circuit capacity for the purpose of controlling the available electric capacity of a
backup circuit connection, this service, if available, will be provided on an annual
contract basis at a level at least sufficient to meet probable backup demand (in kilowatts)
as determined by the customer and approved by the utility according to the following:
(1) Monthly charge shall be the sum of the following charges:
Contracted backup capacity per month Per kW $1.01
Metered kilowatts in excess of the contracted amount Per kW $3.03
(2) In the event the contractual kilowatt limit is exceeded, a new annual
contract period will automatically begin as of the month the limit is exceeded. The
metered demand in the month of exceedance shall become the minimum
contracted demand level for the excess circuit charge.
. . .
(u) Net metering.
. . .
-14-
(5) The customer-generator's consumption of energy from the utility and
production of energy that flows into the utility's distribution system shall be
measured on a monthly basis. The energy consumed from the utility by the
customer-generator shall be billed at the applicable rate as outlined in Subsection
(c) of this Section. The energy produced by the customer-generator shall be
credited to the customer monthly as follows:
a. Summer season energy credit Per kWh $0.0443
Section 7. That Sections 26-469 (c) through (g) and (v) of the Code of the City of
Fort Collins are hereby amended to read as follows:
Sec. 26-469. General service 750, schedule GS750.
. . .
(c) Monthly rate. The monthly rates for this schedule shall be the sum of the
following charges:
(1) Fixed Charge Per account $15.56
a. Additional charge for each additional metering point Per account $9.50
b. An additional charge may be assessed if telephone
communication service is not provided by the customer.
Per account $40.00
(2) Coincident demand charge
a. summer season billing months of June, July and August Per kW $11.51
b. non-summer season billing months of January through
May and September through December
Per kW $8.77
c. The meter reading date shall generally determine the
summer season billing months; however, no customer
shall be billed more than three (3) full billing cycles at
the summer rate.
(3) Distribution facilities charge
a. First seven hundred fifty (750) kilowatts Per kW $6.00
b. All additional kilowatts Per kW $3.55
(4) Energy charge
a. Summer season billing months of June, July, and August Per kWh $0.0436
b. Non-summer season billing months of January through
May and September through December
Per kWh $0.0419
-15-
c. The meter reading date shall generally determine the
summer season billing months; however, no customer
shall be billed more than three (3) full billing cycles at
the summer rate.
(5) Payment in lieu of taxes (PILOT) and franchise.
A charge based on all monthly service charges billed pursuant to this
Section
6 percent
(d) Renewable resource. Renewable energy resources, including, but not limited to,
energy generated by the power of wind, may be offered on a voluntary basis to customers
at the premium per kilowatt hour set forth in this Subsection (d). The utility may establish
and offer voluntary programs designed to increase and enhance the use of energy
generated by renewable energy resources in support of Council-adopted policy applicable
to the utility.
Per kWh $0.025
(e) Excess capacity charge. The monthly capacity charge per kilowatt set forth in this
Subsection (e) may be added to the above charges for service to intermittent loads in
accordance with the provisions of the Electric Service Standards.
Per kW $2.09
(f) Standby service charges. Standby service, if available, will be provided on an
annual contract basis at a level at least sufficient to meet probable service demand (in
kilowatts) as determined by the customer and approved by the utility according to the
following:
(1) Standby distribution charge.
a. Monthly standby distribution charges shall be paid in the following
amounts
Contracted standby service, this charge shall be in lieu of the distribution
facilities charge.
Per kW $3.41
For all metered kilowatts in excess of the contracted amount Per kW $10.24
. . .
(g) Excess circuit charge. In the event a utility customer in this rate class desires
excess circuit capacity for the purpose of controlling the available electric capacity of a
backup circuit connection, this service, if available, will be provided on an annual
contract basis at a level at least sufficient to meet probable backup demand (in kilowatts)
as determined by the customer and approved by the utility at the following:
-16-
(1) Monthly charge.
. . .
(v) Net metering.
. . .
(5) The customer-generator's consumption of energy from the utility and
production of energy that flows into the utility's distribution system shall be
measured on a monthly basis. The energy consumed from the utility by the
customer-generator shall be billed at the applicable rate as outlined in Subsection
(c) of this Section. The energy produced by the customer-generator shall be
credited to the customer monthly as follows:
a. Summer season energy credit Per kWh $0.0436
Section 8. That Sections 26-470 (c) through (e), and (s) of the Code of the City of
Fort Collins are hereby amended to read as follows:
Sec. 26-470. Substation service, schedule SS.
. . .
(c) Monthly rate. The monthly rates for this schedule shall be the sum of the
following charges:
(1) Fixed Charge Per account $35.38
(2) Coincident demand charge
a. summer season billing months of June, July and August Per kW $11.33
b. non-summer season billing months of January through
May and September through December
Per kW $8.64
c. The meter reading date shall generally determine the
summer season billing months; however, no customer
shall be billed more than three (3) full billing cycles at
the summer rate.
(3) Distribution facilities charge Per kW $2.87
(4) Energy charge
Contracted backup capacity per month Per kW $0.70
Metered kilowatts in excess of the contracted amount Per kW $2.10
-17-
a. Summer season billing months of June, July, and August Per kWh $0.0430
b. Non-summer season billing months of January through
May and September through December
Per kWh $0.0412
c. The meter reading date shall generally determine the
summer season billing months; however, no customer
shall be billed more than three (3) full billing cycles at
the summer rate.
(5) Payment in lieu of taxes (PILOT) and franchise.
A charge based on all monthly service charges billed pursuant to this
Section
6 percent
(d) Renewable resource. Renewable energy resources, including, but not limited to,
energy generated by the power of wind, may be offered on a voluntary basis to customers
at a premium per kilowatt hour. The utility may establish and offer voluntary programs
designed to increase and enhance the use of energy generated by renewable energy
resources in support of Council-adopted policy applicable to the utility.
Per kWh $0.025
(e) Standby service charges. Standby service, if available, will be provided on an
annual contract basis at a level at least sufficient to meet probable service demand (in
kilowatts) as determined by the customer and approved by the utility at the following
rates:
(1) Standby distribution charge.
a. Monthly standby distribution charge:
Contracted standby service, this charge shall be in lieu of the distribution
facilities charge.
Per kW $2.55
For all metered kilowatts in excess of the contracted amount Per kW $7.65
. . .
(s) Net metering.
. . .
(5) The customer-generator's consumption of energy from the utility and
production of energy that flows into the utility's distribution system shall be
measured on a monthly basis. The energy consumed from the utility by the
customer-generator shall be billed at the applicable rate as outlined in Subsection
-18-
(c) of this Section. The energy produced by the customer-generator shall be
credited to the customer monthly as follows:
a. Summer season energy credit Per kWh $0.0430
Section 9. That the amendments herein are effective and shall go into effect as
follows:
a. Amended GS50 & GS750 schedule rates shall apply to all electricity used
on or after January 1, 2017;
b. All other amended schedule rates shall apply to all bills issued on the basis
of meter readings on or after January 1, 2017.
Introduced, considered favorably on first reading, and ordered published this 1st day of
November, A.D. 2016, and to be presented for final passage on the 15th day of November, A.D.
2016.
__________________________________
Mayor
ATTEST:
_______________________________
City Clerk
Passed and adopted on final reading on the 15th day of November, A.D. 2016.
__________________________________
Mayor
ATTEST:
_______________________________
Chief Deputy City Clerk
-1-
ORDINANCE NO. 123, 2016
OF THE COUNCIL OF THE CITY OF FORT COLLINS
AMENDING CHAPTER 26 OF THE CODE OF THE CITY OF FORT
COLLINS TO REVISE WATER RATES, FEES, AND CHARGES
WHEREAS, the City Council is empowered and directed by Article XII, Section 6 of the
Charter of the City of Fort Collins, to by ordinance from time to time fix, establish, maintain and
provide for the collection of such rates, fees or charges for utility services furnished by the City
as will produce revenues sufficient to pay the costs, expenses, and other obligations as set forth
therein; and
WHEREAS, the rates, fees or charges for utility services set forth herein are necessary to
produce sufficient revenues to provide the utility services described herein; and
WHEREAS, the revenue from the rates, fees or charges for utility services set forth
herein shall be used to defray the costs of providing such utility services as required by the
Charter and the City Code; and
WHEREAS, Article III, Chapter 26 of the City Code establishes the water utility as a
utility service furnished by and an enterprise of the City; and
WHEREAS, City Code Sections 26-126, 26-127 and 26-129 concern various water-
related rates, fees, and charges; and
WHEREAS, City Code Section 26-118 requires that the City Manager analyze the
operating and financial records of the utility during each calendar year and recommend to the
City Council user rates or adjustments to be in effect for the following year; and
WHEREAS, the City Manager and City staff have recommended to the City Council
adjustment of the water-related rates, fees, and charges as set forth herein to be effective January
1, 2017; and
WHEREAS, the rate increase for water set forth herein is 5% for all customer classes;
and
WHEREAS, the Water Board considered the proposed water-related rates, fees, and
charges adjustments for 2017 at its meeting on October 20, 2016 and recommended approval of
the proposed adjustments by a unanimous vote; and
WHEREAS, based on the foregoing, City Council desires to amend Chapter 26 of the
City Code to adjust the scope and rate of the water-related rates, fees, and charges as set forth
herein.
NOW, THEREFORE, BE IT ORDAINED BY THE COUNCIL OF THE CITY OF
FORT COLLINS as follows:
-2-
Section 1. That the City Council hereby makes any and all determinations and
findings contained in the recitals set forth above.
Section 2. That Section 26-126 of the Code of the City of Fort Collins is hereby
amended to read as follows:
Sec. 26-126. - Schedule A, flat rates for unmetered construction water use.
For residential and nonresidential premises under construction with a planned meter size
greater than one (1) inch, no flat unmetered water service will be provided. For
residential and nonresidential premises under construction with a planned meter size of
one (1) inch or less, the following flat rates will apply per month until the permanent
meter is set:
¾-inch construction service, flat charge per month $28.26
1-inch construction service, flat charge per month $53.88
Section 3. That Section 26-127 of the Code of the City of Fort Collins is hereby
amended to read as follows:
Sec. 26-127. - Schedule B, meter rates.
(a) Residential rates.
(1) Residential customers with one (1) dwelling unit shall pay the sum of the
following changes:
a. Base monthly charge for residential customers with one (1) dwelling unit $16.18
b. Quantity monthly charge for residential customers with one (1) dwelling
unit
Tier 1 - For the first seven thousand (7,000) gallons used per month, per
one thousand (1,000) gallons
$2.505
Tier 2 - For the next six thousand (6,000) gallons used per month, per one
thousand (1,000) gallons
$2.879
Tier 3 - For all additional gallons used per month, per one thousand
(1,000) gallons
$3.312
(2) Residential customers with two (2) dwelling units shall pay the sum of the
following charges:
a. Base monthly charge for residential customers with two (2) dwelling units $17.13
b. Quantity monthly charge for residential customers with two (2) dwelling
units
-3-
Tier 1 - For the first nine thousand (9,000) gallons used per month, per one
thousand (1,000) gallons
$2.175
Tier 2 - For the next four thousand (4,000) gallons used per month, per
one thousand (1,000) gallons
$2.499
Tier 3 - For all additional gallons used per month, per one thousand
(1,000) gallons
$2.876
(3) Residential customers with more than two (2) dwelling units shall pay the
sum of the following charges:
a. Base monthly charge for residential customers with more than two (2)
dwelling units
First dwelling unit $12.31
Second and each additional dwelling unit $4.10
b. Quantity monthly charge for residential customers with more than two
(2) dwelling units
Winter - per one thousand (1,000) gallons used in the winter season months
of November through April
$1.788
Summer - per one thousand (1,000) gallons used in the summer season
months of May through October
$2.235
The meter reading date shall generally determine the seasonal monthly
quantity charge; however, no customer shall be billed more than six (6) full
billing cycles at the summer quantity charge.
(b) Nonresidential rates.
(1) Base charge. Nonresidential, except for special users as described in
Subsection 26-127(c) below, customers shall pay a base monthly charge based on
meter size as follows:
Meter Size (inches) Monthly Base Charge
¾ $14.31
1 $39.93
1½ $108.58
2 $163.64
3 $249.59
4 $391.83
6 $760.11
8 $1,342.79
-4-
(2) Quantity charges. Nonresidential customers shall pay monthly charges as
follows:
Winter - per one thousand (1,000) gallons used in the winter season
months of November through April
$1.992
Summer - per one thousand (1,000) gallons used in the summer season
months of May through October
$2.489
The meter reading date shall generally determine the seasonal monthly
quantity charge; however, no customer shall be billed more than six (6)
full billing cycles at the summer quantity charge.
(3) Charges for excess use. Nonresidential customers shall also pay monthly
water use charges in excess of the amounts specified in the following table:
Winter - per one thousand (1,000) gallons used in the winter
season months of November through April
$2.861
Summer - per one thousand (1,000) gallons used in the summer
season months of May through October
$3.578
The meter reading date shall generally determine the seasonal
monthly quantity charge; however, no customer shall be billed
more than six (6) full billing cycles at the summer quantity
charge.
Meter Size (inches)
Specified Amount
(gallons per month)
¾ 100,000
1 300,000
1½ 625,000
2 1,200,000
3 1,400,000
4 2,500,000
(c) High volume industrial rates. High volume industrial rates apply to any customer
with an average daily demand in excess of two million (2,000,000) gallons per day. The
specific rate for any qualifying customer shall be based upon the applicable peaking
factor for that customer as follows:
Peaking Factor
Monthly Charge per Thousand
Gallons
1.00—1.09 $1.56
1.10—1.19 $1.62
1.20—1.29 $1.67
-5-
1.30—1.39 $1.72
1.40—1.49 $1.77
1.50—1.59 $1.83
1.60—1.69 $1.88
1.70—1.79 $1.93
1.80—1.89 $1.98
1.90—1.99 $2.05
> 2.00 $2.10
. . .
Section 4. That the modifications set forth above shall be effective for meter readings
on or after January 1, 2017, and in the case of fees not based on meter readings, shall be effective
for all fees paid on or after January 1, 2017.
Introduced, considered favorably on first reading, and ordered published this 1st day of
November, A.D. 2016, and to be presented for final passage on the 15th day of November, A.D.
2016.
__________________________________
Mayor
ATTEST:
_______________________________
City Clerk
Passed and adopted on final reading on the 15th day of November, A.D. 2016.
__________________________________
Mayor
ATTEST:
_______________________________
City Clerk
-1-
ORDINANCE NO. 124, 2016
OF THE COUNCIL OF THE CITY OF FORT COLLINS
AMENDING CHAPTER 26 OF THE CODE OF THE CITY OF FORT
COLLINS TO REVISE WASTEWATER RATES, FEES, AND CHARGES
WHEREAS, the City Council is empowered and directed by Article XII, Section 6 of the
Charter of the City of Fort Collins, to by ordinance from time to time fix, establish, maintain and
provide for the collection of such rates, fees or charges for utility services furnished by the City
as will produce revenues sufficient to pay the costs, expenses, and other obligations as set forth
therein; and
WHEREAS, the rates, fees or charges for utility services set forth herein are necessary to
produce sufficient revenues to provide the utility services described herein; and
WHEREAS, the revenue from the rates, fees or charges for utility services set forth
herein shall be used to defray the costs of providing such utility services as required by the
Charter and the City Code; and
WHEREAS, Article IV, Chapter 26 of the City Code establishes the wastewater utility as
a utility service furnished by and an enterprise of the City; and
WHEREAS, City Code Sections 26-280 and 26-282 concern various wastewater-related
rates, fees, and charges; and
WHEREAS, City Code Section 26-277 requires that the City Manager analyze the
operating and financial records of the utility during each calendar year and recommend to the
City Council user rates or adjustments to be in effect for the following year; and
WHEREAS, the City Manager and City staff have also recommended to the City Council
adjustment of the wastewater-related rates, fees, and charges as set forth herein to be effective
January 1, 2017; and
WHEREAS, the rate increase for wastewater set forth herein is 3% for all customer
classes; and
WHEREAS, the Water Board considered the proposed wastewater-related rates, fees, and
charges adjustments for 2017 at its meeting on October 20, 2016 and recommended approval of
the proposed adjustments by a unanimous vote; and
WHEREAS, based on the foregoing, City Council desires to amend Chapter 26 of the
City Code to adjust the scope and rate of the water-related rates, fees, and charges as set forth
herein.
NOW, THEREFORE, BE IT ORDAINED BY THE COUNCIL OF THE CITY OF
FORT COLLINS as follows:
-2-
Section 1. That the City Council hereby makes any and all determinations and
findings contained in the recitals set forth above.
Section 2. That Section 26-280 of the Code of the City of Fort Collins is hereby
amended to read as follows:
Sec. 26-280. Service charges established by category.
The schedule of rates for each category described in § 26-279 shall be as follows:
Category
Class of
Customer
Rate
A
Single-family residential user
(flat rate)
Per month $39.46
Single-family residential user
(metered water use)
1. Per month $17.63
2. Plus, per 1,000 gallons per month $3.426
Note:
1. For single family customers who have not yet established a winter
quarter water use at the service address, a system average of 4,800
gallons per month shall be billed.
2. After establishment of a winter quarter water use at the service
address, the monthly amount billed shall be based on a minimum of
3,000 gallons per month.
B
Duplex (two-family) residential
users (flat rate)
Per month $54.05
Duplex (two-family) residential
users (metered water use)
Per month $20.02
Or, per 1,000 gallons per month, whichever is
greater, to be calculated on a monthly basis
$3.006
Note:
1. For duplex customers who have not yet established a winter quarter
water use at the service address, a system average 7,200 gallons shall
be billed.
2. After establishment of a winter quarter use at the service address,
the monthly amount billed shall be based on a minimum of 4,000
gallons per month.
C
Multi-family residential user
(more than two dwelling units
including mobile home parks)
and winter quarter based
nonresidential user
1. Base charge per month per dwelling unit
served
$2.61
2. Plus, per 1,000 gallons per month $3.319
Note:
-3-
1. For multi-family customers who have not yet established a winter
quarter water use at the service address, a system average of 3,400
gallons per living unit shall be billed. However, Category D rates will
apply to multi-family residential units under construction during the
period of service from the installation of the water meter to the date
the certificate of occupancy is issued.
2. After establishment of a water quarter use at the service address,
the monthly amount billed shall be per 1,000 gallons of winter quarter
water use, calculated on a monthly basis.
D Minor nonresidential user
1. Per 1,000 gallons of water use, measured
sewage flow or winter quarter water use,
whichever is applicable, to be calculated on a
monthly basis, plus the following applicable base
charge:
$3.130
2. Size of water meter (inches) Base charge
¾ or smaller $9.03
1 $20.85
1½ $41.96
2 $71.80
3 $114.72
4 $181.18
6 $794.25
8 $917.07
E and F
Intermediate nonresidential user
and Significant industrial user
User shall pay an amount calculated to include:
1. Rate per 1,000 gallons of water use,
measured wastewater flow or winter quarter
water use per month, whichever is applicable;
$3.130
2. PLUS a surcharge per million gallons for
each milligram per liter of suspended solids in
excess of 235 milligrams per liter;
$3.641
3. PLUS a surcharge for the following:
a. per million gallons for each milligram per
liter of BOD in excess of 265 milligrams per
liter; or
$3.033
b. per million gallons for each milligram per
liter of COD in excess of 400 milligrams per
liter; or
$1.915
c. per million gallons for each milligram per $5.668
-4-
liter of TOC in excess of 130 milligrams per liter,
whichever is applicable.
The user shall pay the calculated amount based
on 1, 2 and 3 above, plus the applicable base
charge set forth below:
Size of water meter
(inches)
Base charge
¾ or smaller $9.03
1 $20.85
1½ $41.96
2 $71.80
3 $114.72
4 $181.18
6 $794.25
8 $917.07
G User outside City limits
The rate for users outside the City limits shall be the same as for like
service inside the City limits as is specified in Categories A—F and H
in this Section.
H Special with agreement
The rate pursuant to a special wastewater services agreement
approved by the City Council pursuant to § 26-290 shall be set forth in
said agreement.
Section 3. That Section 26-282(a) of the Code of the City of Fort Collins is hereby
amended to read as follows:
Sec. 26-282. - Wastewater strength or industrial surcharges and categories
established.
(a) A monthly wastewater strength surcharge shall be paid by customers located
either inside or outside the City limits in accordance with the following schedule:
Parameter Excess over (mg/l) Rate per thousand gallons
BOD 265 $0.003033
COD 400 $0.001915
TOC 130 $0.005668
TSS 235 $0.003641
. . .
-5-
Section 4. That the modifications set forth above shall be effective for meter readings
on or after January 1, 2017, and in the case of fees not based on meter readings, shall be effective
for all fees paid on or after January 1, 2017.
Introduced, considered favorably on first reading, and ordered published this 1st day of
November, A.D. 2016, and to be presented for final passage on the 15th day of November, A.D.
2016.
__________________________________
Mayor
ATTEST:
_______________________________
City Clerk
Passed and adopted on final reading on the 15th day of November, A.D. 2016.
__________________________________
Mayor
ATTEST:
_______________________________
City Clerk
-1-
ORDINANCE NO. 125, 2016
OF THE COUNCIL OF THE CITY OF FORT COLLINS
AMENDING CHAPTER 26 OF THE CODE OF THE CITY OF FORT
COLLINS TO REVISE STORMWATER RATES, FEES, AND CHARGES
WHEREAS, the City Council is empowered and directed by Article XII, Section 6 of the
City Charter, to by ordinance from time to time fix, establish, maintain and provide for the
collection of such rates, fees or charges for utility services furnished by the City as will produce
revenues sufficient to pay the costs, expenses, and other obligations as set forth therein; and
WHEREAS, the rates, fees or charges for utility services set forth herein are necessary to
produce sufficient revenues to provide the utility services described herein; and
WHEREAS, the revenue from the rates, fees or charges for utility services set forth
herein shall be used to defray the costs of providing such utility services as required by the
Charter and the City Code; and
WHEREAS, Article VII, Chapter 26 of the City Code establishes the stormwater utility
as a utility service furnished by and an enterprise of the City; and
WHEREAS, City Council has adopted stormwater basin and Citywide master plans
recommending stormwater facilities necessary to provide for proper drainage and control of
flood and surface waters within the City; and
WHEREAS, in 1998, City Council adopted Ordinance No. 168, 1998, determining that
all lands within the City benefit by the installation of such stormwater facilities; and
WHEREAS, City Code Section 26-513 imposes stormwater utility fees on all parcels of
land within the City to pay for the operation, maintenance, administration and routine functions
of the existing and future City stormwater facilities established within the City; and
WHEREAS, City Code Section 26-514 sets forth the manner in which stormwater utility
fees are to be determined; and
WHEREAS, the proposed stormwater utility fee adjustment for 2017 reflects an increase
of approximately 5%; and
WHEREAS, the Water Board considered the proposed stormwater utility fee adjustments
for 2017 at its meeting on October 20, 2016, and recommended approval of the proposed
adjustments; and
WHEREAS, based on the foregoing, City Council desires to amend Chapter 26 of the
City Code to adjust the scope and rate of the stormwater utility fee as set forth herein.
NOW, THEREFORE, BE IT ORDAINED BY THE COUNCIL OF THE CITY OF
FORT COLLINS as follows:
-2-
Section 1. That the City Council hereby makes and adopts the determinations and
findings contained in the recitals set forth above.
Section 2. That Section 26-514(a)(3) of the Code of the City of Fort Collins is hereby
amended to read as follows:
Sec. 26-514. - Determination of stormwater utility fee.
(a) The stormwater utility fee shall be determined as set forth in this Section, and shall be
based upon the area of each lot or parcel of land and the runoff coefficient of the lot or parcel.
For the purposes of this Section, the total lot or parcel area shall include both the actual square
footage of the lot or parcel and the square footage of open space and common areas allocated to
such lot as provided in Paragraph (4) of this Subsection. The stormwater utility fee shall recover
the costs of both operations and maintenance and a portion of capital improvements. The
Utilities Executive Director shall determine the rates that shall apply to each specific lot or parcel
of land within the guidelines herein set forth and shall establish the utility fee in accordance with
the rate together with the other factors set forth as follows:
. . .
(3) The base rate for the stormwater utility fee shall be $0.0043526 per square foot
per month for all areas of the City.
. . .
Section 3. That the modifications set forth above shall be effective for all fees
accruing on or after January 1, 2017.
Introduced, considered favorably on first reading, and ordered published this 1st day of
November, A.D. 2016, and to be presented for final passage on the 15th day of November, A.D.
2016.
__________________________________
Mayor
ATTEST:
_______________________________
City Clerk
-3-
Passed and adopted on final reading on the 15th day of November, A.D. 2016.
__________________________________
Mayor
ATTEST:
_______________________________
City Clerk
$3,000,000
$4,000,000
$5,000,000
$6,000,000
$7,000,000
$8,000,000
$9,000,000 Operating Income
$0
$10,000,000
$20,000,000
$30,000,000
$40,000,000
$50,000,000
$60,000,000
2006 2008 2010 2012 2014 2016 2018 2020 2022 2024 2026
Outstanding Debt
$0
$5,000,000
$10,000,000
$15,000,000
$20,000,000
$25,000,000
2006 2008 2010 2012 2014 2016 2018 2020 2022 2024 2026
Available Reserves
0.0%
1.0%
2.0%
3.0%
4.0%
5.0%
6.0% Rate Increase
10.0%
12.0%
14.0% Rate Increase
2006 2008 2010 2012 2014 2016 2018 2020 2022 2024 2026
Outstanding Debt
$0
$5,000,000
$10,000,000
$15,000,000
$20,000,000
$25,000,000
$30,000,000
$35,000,000
2006 2008 2010 2012 2014 2016 2018 2020 2022 2024 2026
Available Reserves
0.0%
1.0%
2.0%
3.0%
4.0%
5.0%
6.0%
7.0% Rate Increase
Operations
$M