HomeMy WebLinkAboutCOUNCIL - AGENDA ITEM - 11/06/2018 - ITEMS RELATING TO 2019 UTILITY RATES FOR ELECTRICAgenda Item 15
Item # 15 Page 1
AGENDA ITEM SUMMARY November 6, 2018
City Council
STAFF
Randy Reuscher, Utility Rate Analyst
Lance Smith, Utilities Strategic Finance Director
Eric Potyondy, Legal
Cyril Vidergar, Legal
SUBJECT
Items Relating to 2019 Utility Rates for Electric and Stormwater Rates, Fees and Charges.
EXECUTIVE SUMMARY
A. First Reading of Ordinance No. 134, 2018, Amending Chapter 26 of the Code of the City of Fort
Collins to Revise Electric Rate, Fees and Charges.
B. First Reading of Ordinance No. 135, 2018 Amending Chapter 26 of the Code of the City of Fort Collins
to Revise Stormwater Rates, Fees and Charges.
The purpose of this item is for Council to consider adjusting monthly charges for electric and storm water
services in 2019. The revenue requirements to support the 2019 budget will require increasing monthly
charges for electric service by 5.0% and stormwater service by 2.0%. Staff recommends no changes to water
and wastewater utility rates.
STAFF RECOMMENDATION
Staff recommends adopting both Ordinances on First Reading.
BACKGROUND / DISCUSSION
The proposed electric rate increase consists of two components. The first component of 1.4% is necessary to
offset the increase in wholesale energy prices. The second component of 3.6% is needed to increase
operating revenues enough to offset operating expenses so that reductions in reserves stop and funds can be
set aside for future capital improvements. More modest increases will be necessary over the coming decade
to support wholesale energy increases, asset renewal, and operations.
While no adjustment of the water and wastewater rates is recommended for this budget cycle, an increase to
stormwater rates by 2.0% in 2019 is proposed. This increase is intended to moderately raise operating
revenues to increase the debt capacity of the Enterprise in anticipation of significant debt being needed to
meet the future capital improvements necessary to complete planned buildout of the stormwater infrastructure.
Similar adjustments of less than 3% may be necessary over the coming decade depending on the timing and
scale of the necessary capital investments.
From a residential customer’s perspective, the net increase to their 4-service utility bill is expected to be 2.2%
or, averaged across each utility service, this is $3.76 per month more than they are paying in 2018. The table
below shows the bill breakdown for residential customers only. See 2019 Proposed Electric Rate Changes of
service for a reflection of rate increases for all classes.
Agenda Item 15
Item # 15 Page 2
Utility 2018 2019 $ Change % Change
Electric $ 71.96 $ 75.41 $ 3.45 4.8%
Water $ 47.88 $ 47.88 $ - 0.0%
Wastewater $ 34.45 $ 34.45 $ - 0.0%
Stormwater $ 15.42 $ 15.73 $ 0.31 2.0%
Total Average Bill $ 169.71 $ 173.47 $ 3.76 2.2%
Average Residential Monthly Bill
Fort Collins Utilities
Rate Strategy and Smoothing
At the beginning of the 2019-2020 Budgeting For Outcomes process, revenues are forecasted for the coming
two years. These forecasted revenues provide the funding for the Enterprise Funds providing the utility
services. Any rate adjustments need to be considered in these forecasts. As rate increases are periodically
necessary to meet operational costs and needs, an objective set of criteria for determining these rate
adjustments is necessary for financial modeling. This set of criteria is based on the objectives outlined in the
overall rate strategy and factor in satisfaction of appropriate maintenance and repairs to the utility systems.
The rate strategy outlined below is intended to maintain the financial health and resiliency of the utility
Enterprise Funds as determined by the bond rating agencies criteria for assessing new debt issuances by
municipal utilities. The strategy seeks to meet the revenue and reserve funding requirements of each utility
through gradual rate increases. It is included in the long-term financial modeling for each utility and serves as
the basis of the rate projections presented to Council since 2016.
The following criteria objectively determine when, why and how much rates should be adjusted to maintain the
financial health of each utility:
1. Adjust electric rates sufficient to meet Platte River Power Authority wholesale rate adjustments.
2. If the previous 3 years have averaged negative operating income, raise rates next year to the lesser of 5%
or the level sufficient to offset the average operating loss.
3. If debt coverage is less than 2.0, increase rates the lesser of 5% and a level sufficient to raise the debt
coverage ratio to 2.1 the next year.
4. If the Available Reserve fund balance is projected to be negative at the end of any year, increase rates the
lesser of 5% and an amount sufficient to increase reserves to the minimum required reserve.
5. Add up all of the previous criteria-driven rate adjustments and take the lesser of 5% and the sum as the
recommended rate adjustment.
By limiting the annual increase to no more than 5.0% in any one utility, the average customer should not see
an increase in their total utility bill by more than 5% in one year. This constraint results in some “smoothing” or
spreading out of larger rate increases over 2 or more years. Moreover, because the total utility bill is
considered, adjustments in one utility may be less than needed in order to smooth out the overall bill impact.
As proposed in this agenda item, for example, the necessary electric rate increase is being smoothed out over
3 years.
Electric Rate Increase
The rate strategy above consists of 5 steps before looking at the overall utility bill impact for any additional
smoothing of the proposed electric rate increase.
Agenda Item 15
Item # 15 Page 3
Step 1 – Purchased Power Adjustment
Platte River Power Authority is expected to increase the Tariff 1 purchase price by 2.0% annually
through 2027. As there is no rate stabilization fund, these increases need to be recovered through
retail rate increases each year. Purchased power costs represent 72% of the operating expenses in
2017 which results in a need for a 1.4% retail rate adjustment to cover this wholesale increase. Both
the summer and non-summer seasons, and the energy and demand components will increase equally.
Below is a table of the current 2018 component charges, along with the proposed 2019 component
charges.
2018 Proposed 2019 % Change
Energy
Summer 0.04284 / kWh 0.04370 / kWh 2.0%
Non-summer 0.04109 / kWh 0.04191 / kWh 2.0%
Demand
Summer 11.56 / kW 11.79 / kW 2.0%
Non-summer 8.81 / kW 8.99 / kW 2.0%
Tariff 7 charges from PRPA for long-term renewable energy purchases are not proposed to change in
2019.
Step 2 – Operating Income
Each Enterprise Fund is expected to generate enough operating income to make itself self-sufficient
and sustainable. Bond underwriters expect that operating expenses are being more than fully covered
by operating revenues. The excess operating income allows for sustainable renewal of the
infrastructure. In addition, the City’s Charter requires rates, fees and charges for each utility “as will
provide sufficient revenues to pay the cost of operation and maintenance . . .”, including payment of a
PILOT, principal and interest on outstanding bonds, provision of adequate working capital for day-to-
day operations, and maintenance of adequate reserves for capital repair, replacement and
improvement of the utility (Art. XII, section 6).
Since 2007 this Fund has utilized reserves to offset operating losses.
($20,000,000)
$0
$20,000,000
$40,000,000
$60,000,000
$80,000,000
$100,000,000
$120,000,000
$140,000,000
$160,000,000
2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017
Light & Power Fund Operating Income (2007-2017)
OPERATING INCOME
Total Operating Revenue
Total Operating Expenses
Agenda Item 15
Item # 15 Page 4
While this was an intentional draw down of reserves based on previous City Council direction, over the
last 3 Budgeting For Outcomes cycles (2013-2018) $41.7M has been appropriated from Reserves.
The reserve balance decreased from a peak of $56.5M in 2014 to $33.5M at the end of 2017. The
table below steps through the reserve balance to show that $11.4M was available for future
appropriations at the end of 2017.
$M
Reserve Balance 12/31/2017 $33.5
LESS Minimum Required Reserves ($8.4)
LESS Appropriations Prior to 12/31/2017 ($9.2)
LESS 2018 Budget Use of Reserves ($4.5)
Reserves Available 12/31/2017 $11.4
LESS 2018 Appropriations to date ($8.4)
LESS 2019-20 Budget Use of Reserves ($0.3)
PLUS 2018 Unanticipated Revenues $2.5
Reserves Available 10/15/2018 $5.2
In addition to the $4.5M use of reserves to support the 2018 budget, an additional $8.4M has been
appropriated from these Reserves for bond defeasance and capital investments through Ordinances in
2018. This leaves a balance of $5.2M available for future appropriations. The 2019-20 biennial budget
will only require the appropriation of $339,000 in 2019 with $317,000 being added back to reserves in
2020. The use of reserves is no longer tenable, making it necessary to increase operating income in
this budget cycle through these rate adjustments.
Based on the financial model, a 5.0% increase in operating revenues in 2019 is necessary to offset the
3-year average operating loss of $4.3M and provide a small operating margin of less than 2%. The
5.0% limit on a single year rate increase means smoothing over multiple years is necessary.
The resulting increase in operating revenues in 2019, which will remain within the City’s electric
distribution utility, along with additional future adjustments, will result in positive operating income
being generated for this Enterprise within the next few years.
Agenda Item 15
Item # 15 Page 5
($20,000,000)
$0
$20,000,000
$40,000,000
$60,000,000
$80,000,000
$100,000,000
$120,000,000
$140,000,000
$160,000,000
$180,000,000
$200,000,000
2007 2009 2011 2013 2015 2017 2019 2021 2023 2025
Light & Power Fund Operating Income (2007-2026)
OPERATING INCOME
Total Operating Revenue
Total Operating Expenses
Step 3 – Debt Coverage
The rating agencies know that investors want as little risk as possible for a given level of return on their
investment. The debt coverage ratio provides a level of confidence that sufficient income will be
generated to ensure that the bondholders are repaid as scheduled.
In this case, there is no outstanding debt expected to be repaid through electric operating revenues, so
this criterion is not requiring any additional rate adjustment.
Step 4 – Capital Investments
The long-term viability of the revenue streams dedicated to bond repayment is also critical to
bondholders and the financial health of the Enterprise. Generating operating income provides a
sustainable revenue stream for asset renewal over time. The rating agencies also want to know that
the utility has a capital improvement plan, a supporting financial plan and that rate adjustments are
part of the plan, as well as seeing adequate investment in the system assets.
Because the currently proposed rate increase is intended to support the 2019-20 budget cycle, the
amount of capital being requested in these two years of $10M / year is reflected in the revenue
requirement rather than the $16M / year described in the CIP. So, capital investment is not driving any
increase above what has already been identified.
Step 5 – Rate Smoothing Over Time
The 5.0% limit on an annual rate increase for each utility will require smoothing anticipated rate
increases over a few years.
Agenda Item 15
Item # 15 Page 6
Criteria 2019 2020 2021
1.4% 0.8%
1. PRPA wholesale energy costs 1.4% 1.4% 1.4%
2. 3 yr ave Operating Income < 0 5.0% 3.0% TBD
3. Debt Coverage Ratio < 2.0 TBD
4. Available Reserves less Capital Need < 0 TBD
Sum of Above 6.4% 5.8%
5. Lesser of 5.0% or the sum of above 5.0% 5.0% TBD
Increase Carried Forward 1.4% 0.8% TBD
TBD - to be determined in the 2021-22 Budget cycle
The financial model forecast shows that modest annual rate adjustments of 1-3% annually may be sufficient
once this increase is smoothed out over the next 3 years.
0%
1%
2%
3%
4%
5%
6%
7%
8%
9%
10%
2007 2009 2011 2013 2015 2017 2019 2021 2023 2025 2027
% Rate Increase
Electric Monthly Rates
Purchased Power
Distribution System
Energy Services
Electric Cost of Service
The cost of service model was updated in 2018 in keeping with the two-year period to avoid large swings
between rate classes in any given year. The rate class percentage adjustments are shown in the graph below.
The horizontal line represents an average retail increase of 5.00%. 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 are dependent on specific costs and allocations to each rate class. As the graphs shows, no
one rate class varies, either higher or lower, by more than one percent from the average of 5.0% increase.
Agenda Item 15
Item # 15 Page 7
To maintain the direct connection between the wholesale charges from Platte River to the retail energy and
coincident demand rates, those components will be increased the same 2.0% as the wholesale increase.
Because these components of the bill are larger than the distribution and fixed charges, it is necessary to
increase those components by more than 5% to achieve the overall revenue requirement and the average bill
increase of 5.0%. The rating agencies consider how much of the fixed costs of a utility are recovered through
fixed charges. A higher percentage of the fixed costs being recovered through fixed charges creates more
revenue stability and therefore more confidence that adequate revenues will be generated in the future to meet
debt obligations.
Net-Metering - Community Solar Projects
In addition to adjusting TOD rates for 2019, this Ordinance temporarily authorizes the Utilities Executive
Director to extend 2018 tiered solar generation bill credits for community solar customers until December 31,
2018. This short-term authorization will allow the Utilities Executive Director to delay application of TOD bill
credit calculations as may be needed to comply with terms in power purchase contracts between the City and
community solar project developers.
Addition of LED Floodlight Charges
Code already accommodates floodlight charges for mercury vapor and high-pressure sodium bulbs. To
accommodate the installation of LED lights as an option for area floodlights, staff had added two new charges
to accommodate fifty-four (54) watt and seventy-two (72) watt fixtures.
Stormwater Rate Increase
Step 1 – Operating Income
Operating income is strong in this utility, so no adjustment is necessary to satisfy the operational,
maintenance and reserve-funding requirements of the Charter.
Agenda Item 15
Item # 15 Page 8
Step 2 – Debt Coverage Ratio
The debt coverage ratio continues to grow as existing debts are retired. Again, no adjustment is
necessary.
Step 3 – Capital Investments
The 2% stormwater increase for 2019 is intended to raise operating revenues modestly to increase the
debt capacity of the Enterprise. This is in anticipation of significant debt being needed for the capital
improvements necessary to complete the initial buildout of the stormwater infrastructure. Similar,
modest adjustments of less than 3% may be necessary over the coming decade depending on the
timing and scale of the necessary capital investments and to manage reserve balances.
Step 4 – Rate Smoothing Over Time
Criteria 2019
1. 3 yr ave Operating Income < 0
2. Debt Coverage Ratio < 2.0
4. Available Reserves less Capital Need < 0 2.0%
Sum of Above 2.0%
5. Lesser of 5.0% or the sum of above 2.0%
No additional smoothing is necessary, nor is it expected over the coming decade. Modest rate
increases may be necessary to cover higher costs as the operating margin decreases gradually over
the decade.
0%
1%
2%
3%
4%
5%
6%
7%
8%
9%
10%
2007 2009 2011 2013 2015 2017 2019 2021 2023 2025 2027
% Rate Increase
Stormwater Monthly Rate Changes
Low-Income Support Programs
Agenda Item 15
Item # 15 Page 9
Utilities manages a robust Utilities Affordability Portfolio along with the Income Qualified Assistance Program to
support at-risk populations. Staff has worked with local service providers, regional partners, and subject
matter experts to identify participation barriers for low income customers, and ensure the providers have the
information and engagement they need to direct low-income customers to our programs and services. Utilities
has implemented engagement and communication strategies to address barriers and help residents more
easily participate in our low-income programs. A comprehensive communication, outreach and engagement
strategy is the cornerstone of resident awareness and participation. Please see the attached City Council
memo summaries on programs and results. Costs of these programs have been considered in connection
with the proposed rate increases.
CITY FINANCIAL IMPACTS
Electric Rate Ordinance – In 2019 the proposed 5.0% increase would add an estimated $6.5M to operating
revenues which will partially address the ongoing operating loss and decrease reliance on reserves. The
attached one-page budget summary for the Light and Power Enterprise Fund (Attachment 7) shows the
budget assuming this proposed 5.0% rate increase is adopted. Because reserves have been drawn down
already any reduction in the proposed 5.0% rate increase would need to be offset by a corresponding amount
in the accepted budget offers.
Stormwater Rate Ordinance – In 2019 the proposed 2.0% increase would add an estimated $0.3M to
operating revenues. In the near term, this modest rate increase will allow the utility to build up reserves to
strengthen the utility’s financial position ahead of anticipated debt issuances. The attached one-page budget
summary for the Stormwater Enterprise Fund (Attachment 7) shows a contribution to reserves in both years.
In the long term this will increase the debt capacity necessary to finance the remaining stormwater
infrastructure.
BOARD / COMMISSION RECOMMENDATION
Energy Board: The Board reviewed the rate proposal at its regular meeting on October 11, 2018.
Chairperson Michell moved that the Energy Board support a 5% rate increase, as proposed by staff, plus an
additional 0.63% to support the optional CAP offer package, allowing the City to meet its 2020 CAP goals.
Furthermore, the Energy Board does not support cutting funding for capital infrastructure to support the
optional CAP offer package. The motion passed unanimously.
Water Board: The Board reviewed the rate proposal at its regular meeting on October 18, 2018. Board
Member Michael Brown moved for Water Board to recommend City Council approve the 2019 rate changes for
stormwater monthly fees. The motion passed unanimously.
PUBLIC OUTREACH
Key Accounts has been communicating with customers about the 5.0% rate increases being proposed in 2019
and 2020.
A memo was requested by the Chamber of Commerce before First Reading in lieu of a presentation due to the
lack of availability in the Chambers schedule until late November when City staff will provide an update on
several utility issues including these rate increases.
Agenda Item 15
Item # 15 Page 10
ATTACHMENTS
1. Energy Board Minutes October 11, 2018 (Draft) (PDF)
2. Water Board Minutes (Draft) (PDF)
3. Fund Summaries - Electric and Stormwater Only (PDF)
4. Memo - Utilities Affordability Portfolio and IQAP update (PDF)
5. Utilities Affordability Portfolio & Programs Memo (PDF)
6. Utilities Affordability Portfolio Goals Memo (PDF)
7. Utilities Affordability Portfolio Outreach Memo (PDF)
8. PowerPoint Presentation (PDF)
Energy Board Minutes
ABRIDGED - DRAFT October 11, 2018
Energy Board Minutes
ABRIDGED - DRAFT October 11, 2018
Fort Collins Utilities Energy Board Minutes
ABRIDGED - DRAFT Thursday, October 11, 2018
Energy Board Chairperson
Nick Michell, 970-215-9235
City Council Liaison
Ross Cunniff, 970-420-7398
Energy Board Vice Chairperson
Amanda Shores, 408-391-0062
Staff Liaison
Tim McCollough, 970-305-1069
Roll Call
Board Present: Chairperson Nick Michell, Vice Chairperson Amanda Shores, Alan Braslau, Stacey
Baumgarn, Bill Becker, Jeremy Giovando, Greg Behm, John Fassler, Krishna Karnamadakala
Late Arrivals:
Board Absent:
Others Present
Staff: Tim McCollough, Christie Fredrickson, Lindsay Ex, John Phelan, Lance Smith
Platte River Power Authority: Paul Davis, Alyssa Clemson-Roberts
Members of the Public:
Budgeting for Outcomes
Tim McCollough, Deputy Director Utilities Light & Power
(attachments available upon request)
Council has had three budget work sessions and two public hearings, and there is an additional work
session scheduled for next week. As Mr. Smith noted in his earlier presentation, there is a
recommended 5% rate increase to support the City Manager’s Recommended Budget. Mr. McCollough
said Council does support many of the programs within the Climate Action Plan optional budget package
that was discussed at last month’s Energy Board Meeting, but they have asked staff if there is a way to
continue those programs within the already proposed 5% rate increase. Mr. McCollough said that
would mean adjusting other offers already on the table, such as reducing some of Light & Power’s
capital needs, or finding additional revenue sources. Staff doesn’t have additional details at this time,
but Mr. McCollough wanted the board to be informed about the request from Council.
Vice Chairperson Shores asked why Council does not want to exceed a 5% rate increase, because an
additional 0.63% would likely be a fraction of a dollar on an average household utility bill. Mr.
McCollough said this meeting didn’t provide an opportunity for staff to discuss with City Council, but
rather for City Council to provide feedback on the information they were presented and request a follow
up from staff. Board member Braslau said he believes it is a mistake to make budget choices that allows
the City to miss it’s 2020 CAP goal; he also said the recommended budget seems inconsistent with the
recent decision to commit to 100% Renewable Energy. Vice Chairperson Shores said relaying
information in percentages is ineffective, because at the end of the day most people only care about the
ATTACHMENT 1
Energy Board Minutes
ABRIDGED - DRAFT October 11, 2018
Energy Board Minutes
ABRIDGED - DRAFT October 11, 2018
cost of their monthly bill, and perhaps it would be more effective to explain how much 0.63% translates
to monetarily and what services that rate increase would be providing to the community.
Chairperson Michell said in the past there have been several great efficiency programs marketed, just
like some of the CAP programs that are currently on the chopping block, but by February all the funding
has run out and they expect customers to come back the following year. He believes Council should
either fund or not fund efficiency programs like that so there isn’t such a drastic swing between funding
cycles. Mr. Davis said the Platte River Power Authority efficiency budget grew by 20% this year, and
though it is somewhat complicated, he does not believe some of the larger efficiency programs, such as
Efficiency Works Business, are in any danger of running out of funding. Mr. Smith said it’s important to
add context: In the 2019/2020 budget, staff is proposing $18.3 million in renewable energy and green
initiatives, and the question now is do we invest $19.6 million in those initiatives. He wanted the board
to remember it’s not as if the City isn’t doing anything, and Platte River is also contributing an additional
$4 million. It’s Mr. Smith’s opinion the City will not even be able to use all $18 million currently allotted,
because in recent history there have always been funds left over in that budget line. Mr. Smith believes
it would be wiser to invest more money into capital. Mr. McCollough reiterates support for Mr. Smith’s
statements and added that deferring capital investments comes with its own set of concerning
problems.
Chairperson Michell moved that the Energy Board support a 5% rate increase, as proposed by staff,
plus an additional 0.63% to support the optional CAP offer package, allowing the City to meet its 2020
CAP goals. Furthermore, the Energy Board does not support cutting funding for capital infrastructure
to support the optional CAP offer package.
Board member Behm seconded the motion.
Discussion:
Board members asked Mr. Smith what the overall financial impact would be to an average residential
bill with a 5.63% rate increase and the assumed Time of Day usage reductions. Mr. Smith estimated it
would be approximately $3.38 more per month. Board member Baumgarn asked if voting on this
motion is as impactful as the Board hopes, since they voted on a very similar motion at last month’s
meeting. He wondered if the Board should consider another avenue of communication such as a memo.
Vote on the Motion: It passed unanimously, 9-0.
Board members discussed attending the October 16 City Council meeting, so they can ensure their
opinions are heard in addition to their motions and votes.
Excerpt from Unapproved DRAFT MINUTES WATER BOARD
REGULAR MEETING
October 18, 2018, 5:30 p.m.
222 Laporte Avenue, Colorado River Community Room
10/18/2018 – Excerpt from Unapproved DRAFT MINUTES Page 1
o Proposal to Increase Stormwater Rates for 2019/Plan Investment Fee Update
(Attachments available upon request)
Presentation Summary: Utility Rate Analyst Randy Reuscher provided an
overview. Staff proposes a 2% increase to stormwater monthly charges for 2019.
The ordinance will be discussed as part of the upcoming City Council agendas
on November 6 and 20, 2018 for first and second readings. No changes are
proposed for water or wastewater monthly charges. Staff also proposes changes
to water, wastewater, and stormwater plant investment fees (PIF) for 2019.
These ordinances are scheduled to be included for discussion at the December
4 and 18 City Council meetings.
Mr. Reuscher summarized the proposals and showed how the rate changes will
affect the average residential monthly bill. Board members commented on and
inquired about various related topics including Stormwater revenue; reserves;
general fund; the Stormwater Fund graph and the desire to show what reserves
would be without the rate increases, and how they affect future capital projects;
the need for marketing staff to explain to the public that these rate increases are
paying for capital projects; how much infrastructure is paid by new development
fees (the fees are intended to cover upfront costs; monthly fees cover the
remainder).
o Board Member Brown moved for Water Board to recommend City Council
approve the 2019 rate changes for stormwater monthly fees and plant
investment fees for water, wastewater, and stormwater, as proposed by staff.
o Board Member Tarry seconded the motion
o Vote on the Motion: It passed unanimously, 8-0.
ATTACHMENT 2
LIGHT & POWER FUND
########
Actual 2015 Actual 2016 Actual 2017 Budget 2018 Budget 2019 Budget 2020 2019 2020
REVENUE PROJECTION
Operating Revenue $117,450,191 $125,072,991 $128,730,192 $130,530,000 $135,573,000 $140,395,000
% Change 6.5% 2.9% 1.4% 3.9% 3.6%
PIF / Contributions $4,435,202 $6,363,132 $5,490,709 $3,130,000 $3,230,000 $3,230,000
% Change 43.5% -13.7% -43.0% 3.2% 0.0%
All Other Revenues $2,691,707 $2,586,182 $2,785,561 $2,202,456 $2,069,686 $1,844,020
% Change -3.9% 7.7% -20.9% -6.0% -10.9%
Total Revenues $124,577,100 $134,022,305 $137,006,462 $135,862,456 $140,872,686 $145,469,020 Revenues $140,872,686 $145,469,020
% Change 7.6% 2.2% -0.8% 3.7% 3.3% Reserves $338,918
$141,211,604
Actual 2015 Actual 2016 Actual 2017 Budget 2018 Budget 2019 Budget 2020
CURRENT OFFERS
Offer Result Title
90.1 Utilities: Light & Power - Payments and Transfers $15,967,002 $17,660,398 $17,180,271 $18,493,708 $16,963,228 $17,315,588
% Change 10.6% -2.7% 7.6% -8.3% 2.1%
8.2 ECON Utilities: Light & Power - Core Operations $9,042,578 $10,435,697 $10,053,255 $10,131,766 $10,490,292 $10,783,807
% Change 15.4% -3.7% 0.8% 3.5% 2.8%
8.3 ECON Utilities: Light & Power - Ongoing Capital
System Additions $9,394,986 $11,689,760 $5,817,270 $5,096,234 $5,355,077 $5,427,972
% Change 24.4% -50.2% -12.4% 5.1% 1.4%
8.4 ECON Utilities - Light and Power Purchase Power $82,164,556 $87,276,576 $89,413,232 $89,500,000 $94,441,000 $97,817,000
% Change 6.2% 2.4% 0.1% 5.5% 3.6%
8.5 ECON Equipment Replacement - Utilities: Light &
Power - Vehicles and Equipment $414,351 $510,427 $392,577 $480,000 $372,000 $522,000
% Change 23.2% -23.1% 22.3% -22.5% 40.3%
9.80 ENVIR Utilities: Light & Power - Energy Services $4,401,391 $4,959,714 $4,539,648 $5,317,950 $4,394,748 $4,439,633
% Change 12.7% -8.5% 17.1% -17.4% 1.0%
9.81 ENVIR Utilities: Light & Power - Residential &
Commercial Solar Rebates $1,211,801 $799,190 $825,680 $710,000 $500,000 $500,000
% Change -34.0% 3.3% -14.0% -29.6% 0.0%
9.82 ENVIR Utilities: Light & Power - Core Renewable Energy $2,249,596 $2,564,237 $2,654,070 $3,874,500 $3,428,300 $3,671,500
% Change 14.0% 3.5% 46.0% -11.5% 7.1%
9.83 ENVIR Utilities: Light & Power - Demand Response $567,069 $1,000,549 $586,908 $620,400 $629,460 $638,663
% Change 76.4% -41.3% 5.7% 1.5% 1.5%
39.2 HPG City Manager's Office $108,145 $111,390
% Change 3.0%
63.1 HPG General Legal Services $86,407 $89,000
% Change 3.0%
87.1 SAFE City Managers Office: Office of Emergency Management $12,000 $13,000
% Change 8.3%
Subtotal Current Offers $125,413,331 $136,896,548 $131,462,912 $134,224,558 $136,780,657 $141,329,553 $136,780,657 $141,329,553
% Change 9.2% -4.0% 2.1% 1.9% 3.3% Less Current $4,430,947 $4,139,467
CAPITAL PROJECTS
Offer Result Title
8.6 ECON Capital Replacement - Utilities: Light & Power - Substation Capital Upgrades $649,000 $624,000
% Change
8.7 ECON Capital Replacement - Utilities: Light & Power - Electric Distribution Transformer Replacement $577,500 $922,600
% Change
8.8 ECON Capital Replacement - Utilities: Light & Power - Attrition Based LED Streetlight Conversion $341,360 $351,600
% Change
8.9 ECON Capital Replacement - Utilities: Light & Power - System Cable Replacement $500,000 $500,000
% Change
12.1 CULTU Utilities Capital Project: Art in Public Places $14,800 $14,076
% Change
Subtotal Capital Projects $4,370,564 $2,082,660 $2,412,276 $2,082,660 $2,412,276
% Change -52.3% 15.8%
TOTAL WITH CAPITAL PROJECTS $125,413,331 $136,896,548 $131,462,912 $138,595,122 $138,863,317 $143,741,829 Less Capital $2,348,287 $1,727,191
ENHANCEMENTS
Offer Result Title
8.12 ECON ENHANCEMENT CAPITAL - Utilities: Light & Power - New Feeder Capacity - Circuit 724 to Serve North College Area $980,000 00
8.15 ECON ENHANCEMENT CAPITAL - Utilities: Light & Power - New Feeder Capacity - Circuit 236 to Serve Drake & Lemay Area $500,000 00
8.25 ECON ENHANCEMENT CAPITAL - Utilities: Light & Power - Supervisory Control Operations Center Remodel $950,000 00
10.15 HPG ENHANCEMENT: 1.0 FTE Utilities (Repurpose): Customer Service & Administration - Data Enhancement ($109,213) ($113,019) 00
10.19 HPG ENHANCEMENT CAPITAL - Utilities: Asset Register and Work Order Management System $435,000 00
10.23 HPG ENHANCEMENT: CAPITAL - Utilities: 700 Wood Street Building/Facilities $160,000 $170,000 00
43.12 ENVIR ENHANCEMENT: 2030 Climate Action and Energy Policy Update –Optimizing Policy, Targets and Strategies (50%) $20,000 $40,000 00
9.90 ENVIR ENHANCEMENT: Utilities: Light & Power - Energy Efficiency $237,500 $237,500 00
9.92 ENVIR ENHANCEMENT: Utilities: Light & Power - Non-Residential Solar Rebates $125,000 $125,000 00
8.13 ECON ENHANCEMENT CAPITAL - Utilities: Light & Power - New Feeder Capacity - Circuit 734 to Serve Downtown Area $590,000 11
8.14 ECON ENHANCEMENT CAPITAL - Utilities: Light & Power - New Feeder Capacity - Circuit 322 to Serve East Prospect & Mulberry Area $820,000 11
8.16 ECON ENHANCEMENT CAPITAL - Utilities: Light & Power - New Feeder Capacity - Circuit 576B to Serve West Harmony Area $457,600 11
8.17 ECON ENHANCEMENT CAPITAL - Utilities: Light & Power - New Feeder Capacity - Circuit 314 to Serve East Prospect Area $700,000 11
8.18 ECON ENHANCEMENT CAPITAL - Utilities: Light & Power - New Duct Bank - County Road 5, Prospect to Mulberry $1,800,000 11
8.22 ECON ENHANCEMENT CAPITAL - Utilities: Light & Power - Arterial & Collector Street LED Streetlight Conversion $773,640 $220,400 11
8.23 ECON ENHANCEMENT CAPITAL - Utilities: Light & Power - Cable Waste Reduction $1,447,983 11
8.24 ECON ENHANCEMENT - Utilities: Light & Power - Mobile Contact Voltage Survey $59,470 $190,960 11
8.26 ECON ENHANCEMENT - Utilities: Light & Power - Automated Vehicle/Crew Location Operational Tech Upgrade $55,000 $20,000 11
8.27 ECON ENHANCEMENT CAPITAL - Utilities: Light & Power - Electric Distribution Training Field $200,000 11
8.29 ECON ENHANCEMENT CAPITAL- Utilities: Light & Power - Overhead to Underground Conversions $516,000 $500,000 11
9.91 ENVIR ENHANCEMENT: Utilities: Light & Power - Cold Weather Pump Demonstration $150,000 $150,000 11
9.94 ENVIR ENHANCEMENT: Utilities: Light & Power - Bring Your Own Thermostat (BYOT) $30,000 $30,000 11
9.95 ENVIR ENHANCEMENT: Utilities: Light & Power - Battery Storage Demonstration $100,000 $100,000 11
9.93 ENVIR ENHANCEMENT: Utilities: Light & Power - Solar Power Purchase Program (SP3) $200,000 11
9.96 ENVIR ENHANCEMENT: 1.0 FTE Conversion to Classified - Energy Code Compliance Specialist - Utilities: Light & Power (50%) $2,135 $2,198 11
87.2 SAFE ENHANCEMENT: OEM $2,300 $2,350 11
Subtotal Enhancements $3,354,870 $8,074,815 $4,802,989 $2,348,287 $1,409,481
TOTAL WITH ENHANCEMENTS $125,413,331 $136,896,548 $131,462,912 $141,949,992 $146,938,132 $148,544,818 Less
Enhancements $0 $317,710
% Change 9.2% -4.0% 8.0% 3.5% 1.1%
Available Reserves
REVENUE PROJECTION LESS ALL OFFERS ($836,231) ($2,874,243) $5,543,550 ($6,087,536) ($6,065,446) ($3,075,798) $338,918 $0 $317,710
WITHDRAWN OFFERS
Offer Result Title
8.11 Econ ENHANCEMENT CAPITAL - Utilities: Light & Power - New Feeder Capacity - Circuit 936 to Serve South Shields Area (Withd $1,280,000
8.19 Econ ENHANCEMENT CAPITAL - Utilities: Light & Power - New Duct Bank - Overland Trail, Drake to Prospect (Hughes Stadium) $1,950,000
8.20 Econ ENHANCEMENT CAPITAL - Utilities: Light & Power - New Duct Bank - Mountain Vista Drive - (Montava) (Withdrawn) $2,200,000
8.21 Econ ENHANCEMENT CAPITAL - Utilities: Light & Power - New Duct Bank - Timberline to I-25 (Withdrawn) $3,770,000
8.28 Econ ENHANCEMENT 1.0 FTE - Utilities: Light & Power - Substation Specialist (Withdrawn) $87,788 $90,943
$3,317,788 $6,060,943
STORMWATER FUND
#######
Actual 2015 Actual 2016 Actual 2017 Budget 2018 Budget 2019 Budget 2020 2019 2020
REVENUE PROJECTION
Operating Revenue $15,035,237 $15,620,342 $16,755,272 $16,210,000 $17,170,000 $17,510,000
% Change 3.9% 7.3% -3.3% 5.9% 2.0%
PIF / Contributions $1,276,385 $1,301,236 $1,078,414 $800,000 $680,000 $570,000
% Change 1.9% -17.1% -25.8% -15.0% -16.2%
All Other Revenues $342,365 $216,332 $567,149 $415,305 $438,325 $457,383
% Change -36.8% 162.2% -26.8% 5.5% 4.3%
Total Revenues $16,653,987 $17,137,910 $18,400,835 $17,425,305 $18,288,325 $18,537,383 Revenues $18,288,325 $18,537,383
% Change 2.9% 7.4% -5.3% 5.0% 1.4%
Less Contribution to Reserves ($1,000,000) ($1,000,000) Available for BFO $17,288,325 $17,537,383
Actual 2015 Actual 2016 Actual 2017 Budget 2018 Budget 2019 Budget 2020 + $500K from NECCO closeout
CURRENT OFFERS $500,000
Offer Result Title
9.100 ENVIR
Utilities: Stormwater - Household
Hazardous Waste & Spill Response
Services
$118,286 $110,587 $122,192 $139,060 $157,000 $157,000 $17,788,325
% Change -6.5% 10.5% 13.8% 12.9% 0.0%
11.2 SAFE Utilities: Stormwater - Core Operations $2,809,365 $3,118,677 $3,358,585 $3,461,280 $3,763,198 $3,887,830
% Change 11.0% 7.7% 3.1% 8.7% 3.3%
11.3 SAFE Capital Replacement - Utilities:
Stormwater - Minor Capital $278,352 $266,843 $280,916 $101,767 $383,232 $533,232
% Change -4.1% 5.3% -63.8% 276.6% 39.1%
90.4 Utilities: Stormwater - Payments and
Transfers $9,623,198 $10,234,652 $10,012,425 $7,590,227 $7,511,987 $6,072,936
% Change 6.4% -2.2% -24.2% -1.0% -19.2%
9.101 ENVIR REDUCTION - Utilities: Stormwater - Household Hazardous Waste Events ($27,400) ($27,400) NOT ACCEPTED
% Change 0.0%
9.102 ENVIR REDUCTION - Utilities: Community Spill Response ($32,400) ($32,400)
% Change 0.0%
63.1 HPG General Legal Services (Stormwater portion) $13,543 $13,950
% Change 3.0%
87.1 SAFE City Managers Office: Office of Emergency Management (Stormwater portion) $38,000 $39,000
% Change 2.6%
Subtotal Current Offers $12,829,201 $13,730,759 $13,774,118 $11,292,334 $11,834,563 $10,671,548 11,834,563 10,671,548
% Change 7.0% 0.3% -18.0% 4.8% -9.8% Less Current $5,953,762 $6,865,835
CAPITAL PROJECTS
Offer Result Title
11.4 SAFE Ongoing Capital - Utilities: Stormwater - Stream Rehabilitation Program $1,400,000 $801,000 $1,408,900 $0 $0
11.5 SAFE $1,500,000 $1,400,000 $1,500,000 $0 $0
Subtotal $2,900,000 $2,201,000 $2,908,900
% Change -24.1% 32.2%
11.6 SAFE Capital Replacement - Utilities: Stormwater - Basin Master Plan Updates $450,000 $450,000 $1 $1
% Change 0.0%
11.7 SAFE Capital Replacement - Utilities: Stormwater - Developer Repayments $300,000 $100,000 $0 $0
% Change -66.7%
12.1 CULTU Utilities Capital Project: Art in Public Places $7,611 $25,462 - -
% Change 234.5%
Other Capital Work Completed in 2017
% Change
Subtotal Capital Projects $2,900,000 $2,958,611 $3,484,362 $2,958,611 $3,484,362
% Change 2.0% 17.8%
TOTAL WITH CAPITAL PROJECTS 12,829,201 13,730,759 13,774,118 14,192,334 14,793,174 14,155,910 Less Capital $2,995,151 $3,381,473
% Change 7.0% 0.3% 3.0% 4.2% -4.3%
ENHANCEMENTS
Offer Result Title
Subtotal Enhancements $4,299,501 $2,182,544 $3,260,225 $2,024,471 $3,123,946
TOTAL WITH ENHANCEMENTS 12,829,201 13,730,759 13,774,118 18,491,835 16,975,718 17,416,135.12 Less
Enhancements $970,680 $257,527
% Change 7.0% 0.3% 34.3% -8.2% 2.6%
Available Reserves
REVENUE PROJECTION LESS ALL OFFERS $3,824,786 $3,407,151 $4,626,717 ($1,066,530) $312,607 $121,248 $1,970,680 $3,228,207
Withdrawn Offers
9.35 ENVIR ENHANCEMENT: 1.0 FTE Utilities: Water/Wastewater/Stormwater Utilities Planner/Scheduler - WITHDRAWN $29,585 $34,248
9.103 ENVIR ENHANCEMENT CAPITAL - Utilities: Pollution Prevention/Good Housekeeping Training Facility - WITHDRAWN $100,000 $0
11.18 Safe ENHANCEMENT: 1.0 FTE Utilities: Stormwater - Civil Engineer II (Stormwater Master Planning) -WITHDRAWN $129,854 $128,697
$259,439 $162,945
Electric
Criteria 2019 2020 2021
1.4% 0.8%
1. PRPA wholesale energy costs 1.4% 1.4% 1.4%
2. 3 yr ave Operating Income < 0 5.0% 3.0% TBD
3. Debt Coverage Ratio < 2.0 TBD
4. Available Reserves less Capital Need < 0 TBD
Sum of Above 6.4% 5.8%
5. Lesser of 5.0% or the sum of above 5.0% 5.0% TBD
Increase Carried Forward 1.4% 0.8% TBD
TBD - to be determined in the 2021-22 Budget cycle
Stormwater
Criteria 2019 2020
1. 3 yr ave Operating Income < 0
2. Debt Coverage Ratio < 2.0
4. Available Reserves less Capital Need < 0 2.0% 2.0%
Sum of Above 2.0% 2.0%
5. Lesser of 5.0% or the sum of above 2.0% 2.0%
Fund 501 Reserves
$M
Reserve Balance 12/31/2017 $33.5
LESS Minimum Required Reserves ($8.4)
LESS Appropriations Prior to 12/31/2017 ($9.2)
LESS 2018 Budget Use of Reserves ($4.5)
Reserves Available 12/31/2017 $11.4
LESS 2018 Appropriations to date ($8.4)
LESS 2019-20 Budget Use of Reserves ($0.3)
Reserves Available 10/15/2018 $2.7
DATE: September 27, 2018
TO: Mayor Troxell and Councilmembers
FROM: Lisa Rosintoski, Deputy Director- Utilities Customer Connections
THROUGH: Darin Atteberry, City Manager
Jeff Mihelich, Deputy City Manager
Kevin R. Gertig, Utilities Executive Director
RE: Utilities Affordability Portfolio and Income Qualified Assistance Program Update
Bottom Line:
In 2018, Utilities staff has worked with local service providers, regional partners, and subject matter
experts to identify participation barriers for low income customers. Most pervasive barriers are
transportation, accessibility, convenience, and access to trusted resources. Utilities has implemented
engagement and communication strategies to address these barriers and help residents more easily
participate in our low-income programs. A comprehensive communication, outreach and
engagement strategy is the cornerstone of resident awareness and participation that is more robust
based on the Time-of-Day (TOD) rate, effective October 1, 2018.
Participation 2018
Direct Assistance: Dollars provided directly to customers in the form of bill payment
assistance. Includes Payment Assistance Fund, Energy Outreach Colorado/Payment
Assistance Fund matching, Solar Affordability Program, and Medical Assistance Program.
The Solar Affordability Program has sunset with the introduction of the Income Qualified
Assistance Program. Accruing solar credits will be used to assist low-income customers in
early 2019.
Indirect Assistance: Dollars provided indirectly to customers in the form of efficient
materials installation or services that increase energy and water efficiency. Includes Larimer
County Conservation Corp, Nonprofit Energy Efficiency Program (NEEP), and Colorado’s
Affordable Energy Efficiency Program (CARE).
DocuSign Envelope ID: F4E9F08D-4988-4ADA-8377-119606478D07
9/26/2018
9/26/2018
9/26/2018
9/27/2018
ATTACHMENT 4
2018 Portfolio Status Updates
2016 2017 2018
ALL Affordability Program Assistance Dollars Total
$204,483
$275,054
$353,370
ALL Affordability Program Assistance Household Total
877
1,100
1,534
ALL Affordability Program Assistance Average
Dollars/Household
$233
$250
$230
Direct Assistance Dollars Total
$120,269
$147,574
$137,213
Direct Assistance Households* 499 661 556
Direct Assistance Average Dollars/Household
$241
$223
$247
Indirect Assistance Household Total
$84,214
$127,480
$216,157
Indirect Assistance Customers** 378 439 978
Indirect Assistance Average Dollars/Household
$223
$290
$221
*IQAP data not included due to 10/1/18 start date
**includes Larimer County Conservation Corp, Energy
Outreach Colorado Efficiency Projects (i.e. Nonprofit
Energy Efficiency Program), Colorado Energy
Assistance Program
Utilities Affordability Program Participation Savings per household/year Total Investment
*1,126 applications sent to qualified LEAP participants; 74% enrollment rate
Larimer County Conservation Corp
$100,000
Income Qualified Assistance Program (IQAP)*
Medical Assistance Program
Payment Assistance Fund
Colorado’s Affordable Energy Efficiency Program (CARE)
EOC Efficiency Programs (NEEP/MFU)
Solar Affordability Program
$244
829
131
325
53
500
19
425
23% rate reduction
$127, 19% Utility bill reduction
$251
16% gas, 8% electric reduction
Engagement and Outreach Plans
Increase outreach and visibility of Utility Affordability programs through strengthened partnerships,
and increased community education and outreach.
Provide UAP information at community-centered locations, i.e. Senior Center and Northside
Aztlan
Provide information at income-qualified residential facilities where residents are billed
separately and would be able to participate in program offerings (i.e. Woodbridge Senior
Living, etc)
Work with multifamily properties, tenants, and other identified groups to provide behavior
change guidance, educational opportunities, and inform of available programs and services
Offer UAP materials and website information in Spanish
Send IQAP application through direct mail and via email communication to qualified LEAP
residents
Community-wide awareness of programs through Utilities bill inserts, social
media/Facebook, partners
Leverage existing community events to engage low-income customers
Provide 1:1 interaction in Utilities Administration Building lobby during LEAP application
period
Maintain seasonally appropriate outreach campaigns to provide ongoing engagement
strategies
2018-2019 Strategic Partnerships
Collaborate with low-income service providers such as La Familia-The Family Center and
Catholic Charities to provide UAP materials and customer education resulting in simple,
streamlined application processes
Partner with Discover Goodwill’s Mission in Motion (mobile office) for LEAP sign-up days
to provide a convenient, customer focused application process
Collaborate with other key stakeholders including Social Sustainability Department, Senior
Advisory Board, and Energy Outreach Colorado to effectively reach low-income customers
Partner with the Professional for Seniors group and attend the December Children in Need
event
Collaborate with Finance, Sustainability and Recreation to explore cross-promotion
opportunities
Work with cross-City team to explore consolidated low-income application options
Integrate messaging and outreach with Sustainability and Neighborhood Services where
possible
DocuSign Envelope ID: F4E9F08D-4988-4ADA-8377-119606478D07
Partner with Housing Catalyst and PSD to leverage non-LEAP income-qualifying programs;
explore other income-qualification platforms to maximize our reach and impact to target
audience in the future
Communicate with Boards, Commissions and impacted stakeholder/trade organizations
Ongoing and expanded service provider engagement
o Regular email communications
o Host annual gathering to share information
o Attendance at appropriate community group meetings
o Offering educational resources and support
o Facilitating meetings or presentations
o Event presence and materials distribution
o Neighborhood canvassing
CC: Cyril Vidergar, Assistant City Attorney
Randy Reuscher, Utility Rate Analyst
Gretchen Stanford, Community Engagement Manager
Crystal Shafii, Program Coordinator Supervisor
DocuSign Envelope ID: F4E9F08D-4988-4ADA-8377-119606478D07
ATTACHMENT 5
ATTACHMENT 6
Utilities
electric · stormwater · wastewater · water
222 Laporte Ave.
PO Box 580
Fort Collins, CO 80522-0580
970.212.2900
V/TDD: 711
utilities@fcgov.com
fcgov.com/utilities
DATE: October 9, 2018
TO: Mayor Troxell and Councilmembers
FROM: Lisa Rosintoski, Deputy Director, Utilities Customer Connections
THROUGH: Darin Atteberry, City Manager
Jeff Mihelich, Deputy City Manager
Kevin Gertig, Utilities Executive Director
RE: Leadership Planning Team Request - Utilities Affordability Portfolio Outreach
This memo is in response to the October 8 Leadership Planning Team request on how customers are
informed about available programs within the Utilities Affordability Portfolio. Below are the identified
outreach tactics and associated metrics for 2018.
Bottom Line:
The Utilities Affordability Portfolio outreach is an annual campaign to educate customers regarding the
programs that provide direct and indirect financial assistance and education for at risk populations. The UAP
campaigns achieve increased donations to the Payment Assistance Fund, and increased program participation
year over year.
2018 Outreach Overview
Outreach Type Description Reach
Bill Insert/City News
Various print pieces sent through Utility bills to
all customers
10 individual pieces/touches to ~49,000
customers each time
Community Events Relevant community-attended events 22 events/presentations
Direct Mail/Email
Targeted to: LEAP participants, MAP/SAP
customers, PAF donors
>10 individual targeted communication to
~3000 customers
General Outreach
IVR message, distributed posters, external
newsletters, press release, etc
>16 general community outreach awareness
and promotion
Lobby Presence
Bilingual staff member/volunteer hosted info
booth at 222 Laporte Ave 17.75 staff hours over 2-month period
Partnerships
Agencies and partner communications in
person and via email >60 agencies/partners contacted
Social Media
Comprehensive social media
(Facebook)campaigns September through April
>10 social media ads/promos reaching 16,176
people
Utilities Website UAP web pages up year-round updates, seasonal promotions
cc: Gretchen Stanford, Community Engagement Manager
Crystal Shafii, Program Coordinator Supervisor
DocuSign Envelope ID: 03E32C0D-8E53-4831-BCD6-B491499CAA11
2019
Kevin R. Gertig, Utilities Executive Director
Lance Smith, Utilities Strategic Finance Director
ATTACHMENT 8 11.06.2018
2019 Rate Summary
2
UTILITY
2019 PROPOSED
INCREASE
NOTES
ELECTRIC 5% Varies by rate class
WATER 0%
WASTEWATER 0%
STORMWATER 2% Same for all rate classes
ELECTRIC
RATES
3
Light & Power Fund Operating Income
4
($20,000,000)
$0
$20,000,000
$40,000,000
$60,000,000
$80,000,000
$100,000,000
$120,000,000
$140,000,000
$160,000,000
2007 2008 2009 2010 2011 2012 2013 2014 2015 2016 2017
Light & Power Fund Operating Income (2007-2017)
OPERATING INCOME
Total Operating Revenue
Total Operating Expenses
Financial Criteria for Rate Adjustments
5
Criteria 2019 2020 2021
1. PRPA wholesale energy costs 1.4% 1.4% 1.4%
Criteria 2019 2020 2021
1. PRPA wholesale energy costs 1.4% 1.4% 1.4%
2. 3 yr ave Operating Income < 0 5.0% 3.0% TBD
Criteria 2019 2020 2021
1. PRPA wholesale energy costs 1.4% 1.4% 1.4%
2. 3 yr ave Operating Income < 0 5.0% 3.0% TBD
3. Debt Coverage Ratio < 2.0 TBD
Criteria 2019 2020 2021
1. PRPA wholesale energy costs 1.4% 1.4% 1.4%
2. 3 yr ave Operating Income < 0 5.0% 3.0% TBD
3. Debt Coverage Ratio < 2.0 TBD
4. Available Reserves less Capital Need < 0 TBD
Criteria 2019 2020 2021
1.4% 0.8%
1. PRPA wholesale energy costs 1.4% 1.4% 1.4%
2. 3 yr ave Operating Income < 0 5.0% 3.0% TBD
3. Debt Coverage Ratio < 2.0 TBD
4. Available Reserves less Capital Need < 0 TBD
Sum of Above 6.4% 5.8%
5. Lesser of 5.0% or the sum of above 5.0% 5.0% TBD
Increase Carried Forward 1.4% 0.8% TBD
TBD - to be determined in the 2021-22 Budget cycle
Electric Rate History / Forecast
0%
1%
2%
3%
4%
5%
6%
7%
8%
9%
10%
2007 2009 2011 2013 2015 2017 2019 2021 2023 2025 2027
% Rate Increase
Electric Monthly Rates
Purchased Power
Distribution System
Energy Services
2019 Cost of Service
STORMWATER
RATES
8
Financial Criteria for Rate Adjustments
9
Criteria 2019 2020
1. 3 yr ave. Operating Income < $0 - -
3. Debt Coverage Ratio < 2.0 - -
4. Available Reserves less Capital Need < 0 * 2.0% 2.0%
Sum of Above 2.0% 2.0%
5. Lesser of 5.0% or the sum of above 2.0% 2.0%
* This is an estimate in lieu of the capital improvement plan
being prioritized. It will be necessary to increase revenues
to support the significant capital needs for this utility
10
Stormwater Rate History / Forecast
0%
1%
2%
3%
4%
5%
6%
7%
8%
9%
10%
2007 2009 2011 2013 2015 2017 2019 2021 2023 2025 2027
% Rate Increase
Stormwater Monthly Rate Changes
UTILITY COST
COMPARISON
11
2018 Comparison - Residential
12
Electric Water Wastewater Stormwater Total
2018 2018 2018 2018 2018
Longmont $ 65.25 $ 45.03 $ 32.71 $ 13.05 $ 156.04
Greeley $ 79.38 $ 54.45 $ 19.74 $ 10.92 $ 164.49
Loveland $ 73.41 $ 44.84 $ 30.65 $ 16.24 $ 165.13
Ft Collins $ 71.96 $ 47.88 $ 34.45 $ 15.42 $ 169.71
Boulder $ 79.38 $ 44.08 $ 35.09 $ 15.61 $ 174.16
Colorado Springs $ 87.13 $ 85.91 $ 28.63 N/A $ 201.66
2019 Rate Adjustments
in Neighboring Communities
13
ELECTRIC WATER WASTEWATER STORMWATER
OVERALL OVERALL OVERALL OVERALL
Loveland 5.00% 9.00% 11.00% 8.30%
Longmont 0.00% 9.00% 2.00% 5.00%
Boulder 7.00% 5.00% 5.00%
Ft Collins 5.00% 0.00% 0.00% 2.00%
RESIDENTIAL
BILL IMPACTS
14
Proposed 2019 Average Residential Bill
Utility 2018 2019 $ Change % Change
Electric $ 71.96 $ 75.41 $ 3.45 4.8%
Water $ 47.88 $ 47.88 $ - 0.0%
Wastewater $ 34.45 $ 34.45 $ - 0.0%
Stormwater $ 15.42 $ 15.73 $ 0.31 2.0%
Total Average Bill $ 169.71 $ 173.47 $ 3.76 2.2%
Average Residential Monthly Bill
Fort Collins Utilities
16
Light & Power Fund Reserves
17
$M
Reserve Balance 12/31/2017 $33.5
LESS Minimum Required Reserves ($8.4)
LESS Appropriations Prior to 12/31/2017 ($9.2)
LESS 2018 Budget Use of Reserves ($4.5)
Reserves Available 12/31/2017 $11.4
LESS 2018 Appropriations to date ($8.4)
LESS 2019-20 Budget Use of Reserves ($0.3)
PLUS 2018 Unanticipated Revenues $2.5
Reserves Available 10/15/2018 $5.2
Light & Power Fund CIP
18
$0
$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
Light & Power Fund Capital Improvement Plan
New Capacity Fiber Optics Improvements
Substation Improvements Operational Technology
Distribution System Improvements Annexations
Service Area - wide Historical Ave Capital 2007-16
Ave Capital Investment 2017-26 Previous CIP Estimated 2017-2026 Capital Investment
Utility Affordability Portfolio
19
Colorado
Affordable
Residential
Energy
(Deep Retrofits)
Income-
Qualified
Assistance
Program
(Discounted
Rate)
Medical
Assistance
Program
(Long-term
Assistance)
Payment
Assistance
Fund
(Short-term
Assistance)
Water and
Energy
Program
(Basic Retrofits)
-1-
ORDINANCE NO. 134, 2018
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
AND UPDATING RELATED PROVISIONS
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, revenues 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 will increase the City’s wholesale cost of power approximately 2.0%
in 2019; and
WHEREAS, Utilities staff has determined the increased wholesale power cost will
require an average 1.4% retail rate increase and increased local distribution costs will require an
additional average 3.6% rate increase, for a total City retail electric rate increase in 2019 of 5.0%
in order to remain consistent with Article XII, Section 6, of the City Charter; and
WHEREAS, the proposed rate increase will vary based on the cost of service to each
customer class; and
WHEREAS, on November 21, 2017, City Council adopted Ordinance No. 155, 2017,
transitioning electric service rates from tiered to a “time-of-day” (“TOD”) based structure for all
meter readings on or after October 1, 2018; and
WHEREAS, in addition to adjusting electric rates, 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, on September 18, 2018, City Council adopted Ordinance No. 116, 2018,
extending tiered-based electric rates for customers enrolled in manual-read metering service as of
August 31, 2018, while all other customers transitioned to TOD on October 1, 2018; and
-2-
WHEREAS, staff recommends continuing tiered-based electric rates for manual-read
metering service customers until completion of upgrades to metering equipment necessary to
serve those customers on TOD rates, while all other customers will transition to updated TOD
rates on January 1, 2019; and
WHEREAS, staff recommends City Council authorize the Utilities Executive Director to
extend until December 31, 2018, tiered solar generation bill credits and delay implementing
TOD credit rates for community solar projects where power purchase agreements with operators
allow the City to change the solar credit only once annually, as extending tiered credits for these
projects will avoid potential contract compliance issues; and
WHEREAS, the Energy Board considered the proposed electric rates and methods of
application at its September 13 and October 11, 2018 regular meetings, and provided
recommendations of approval of proposed rate sets to City Council; and
WHEREAS, the City Manager and staff have recommended to the City Council the
following TOD-based electric rate adjustments and City Code rate language clarifications for all
billings issued with meter readings on or after January 1, 2019; 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), (d), (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.
(1) Tiered Rate - Limited-Term. The monthly rates for this schedule shall be
the sum of the following charges, applied to all remote-read meter readings on or
after January 1, 2018, through September 30, 2018. Customers enrolled in manual
meter reading services as of August 31, 2018 shall remain on the tiered rates
below until the date meter upgrades necessary to serve such customers on time-of-
day rates are completed, as which time the time-of-day rates under subsection (2)
of this Section shall apply.
a. Fixed Charge Per account $5.81
-3-
$6.40
b. Distribution facilities charge Per kWh
$0.0257
$0.0283
c. Energy and demand charge
1. Summer. For billings based on meter readings during the months of June, July
and August, 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
$0.0647
$0.0660
Per kWh
$0.0823
$0.0839
Per kWh
$0.1173
$0.1196
2. Non-summer. For billings based on meter readings during the 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
$0.0595
$0.0607
Per kWh
$0.0638
$0.0651
Per kWh
$0.0729
$0.0744
...
(2) Time-of-day. The monthly rates for this schedule shall be the sum of the
following charges, applied to all remote-read meter readingsenergy consumption
on or after October January 1, 20189. Customers enrolled in manual meter
reading services as of August 31, 2018 shall be billed based on time-of-day rates
as of the date meter upgrades necessary to serve such customers on time-of-day
rates are completed.
a. Fixed Charge Per account
$5.81
$6.40
b. Distribution facilities charge Per kWh
$0.0197
$0.0217
c. Energy and demand charge
1. Summer. For billings based on consumption during the months of May,
June, July, August, and September
(a) On-Peak (Mon-Fri, 2 pm to 7 pm, excluding
holidays)
Per kWh
-4-
(b) Off-Peak
Per kWh
$0.0428
$0.0437
2. Non-summer. For billings based on consumption during the 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
$0.1788
$0.1824
Per kWh
$0.0411
$0.0419
e. 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
$0.0166
$0.0183
...
(d) Medical assistance program.
. . .
(3)
a. Tiered. The discounted monthly rates for customers with electrical durable
medical equipment only shall be the sum of the following charges, applied to all
meter readings on or after January 1, 2018, through September 30, 2018:
1. Fixed Charge Per account $5.81
2. Distribution facilities charge Per kWh $0.0257
3. Energy and demand charge
a) Summer. For billings based on meter readings during the months of June,
July and August, provided that no customer shall be billed more than three
(3) full billing cycles at the summer rate.
(i) Tier 1 - for the first five hundred (500)
kilowatt hours per month
(ii) Tier 2 - for the next five hundred (500)
kilowatt hours per month
(iii) Tier 3 - for all additional kilowatt hours
per month
Per kWh $0.0363
Per kWh $0.0823
Per kWh $0.1173
b) Non-summer. For billings based on meter readings during the months of
January through May and September through December.
(i) Tier 1 - for the first five hundred (500)
kilowatt hours per month, per kWh
(ii) Tier 2 - for the next five hundred (500)
kilowatt hours per month, per kWh
(iii) Tier 3 - for all additional kilowatt hours
Per kWh $0.0325
Per kWh
$0.0638
Per kWh $0.0733
-5-
per month, per kWh
4. Payment in lieu of taxes (PILOT) and franchise.
A charge based on all monthly service charges billed pursuant to
this Section
6 percent
b. Durable Medical Equipment (DME) Time-of-useday. The discounted
monthly rates for customers with electrical durable medical equipment only shall
be the sum of the following charges, applied to all meter readingsenergy
consumption on or after October January 1, 20189:
1. Fixed Charge Per account
$5.81
$6.40
2. Distribution facilities charge Per kWh
$0.0197
$0.0217
3. Energy and demand charge
a) Summer. For billings based on consumption during the months of May,
June, July, August, and September
(i) On-Peak (Mon-Fri, 2 pm to 7 pm,
excluding holidays)
(ii) Off-Peak
Per kWh
$0.1411
$0.1439
Per kWh
$0.0300
$0.0306
b) Non-summer. For billings based on consumption during the months of
January through April and October through December.
(i) On-Peak (Mon-Fri, 5 pm to 9 pm,
excluding holidays)
(ii) Off-Peak
Per kWh
$0.1252
$0.1277
Per kWh
$0.0288
$0.0294
4. 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
$0.0166
$0.0183
...
(4)
a. Tiered. The discounted monthly rates for customers with medical needs
requiring air conditioning only shall be the sum of the following charges, applied
to all meter readings on or after January 1, 2018, through September 30, 2018:
1. Fixed Charge Per account $5.81
2. Distribution facilities charge Per kWh $0.0257
3. Energy and demand charge
-6-
a) Summer. For billings based on meter readings during the months of June,
July and August, and provided that no customer shall be billed more than
three (3) full billing cycles at the summer rate.
(i) Tier 1 - for the first five hundred (500)
kilowatt hours per month
(ii) Tier 2 - for the next five hundred (500)
kilowatt hours per month
(iii) Tier 3 - for all additional kilowatt
hours per month
Per kWh $0.0358
Per kWh $0.0454
Per kWh $0.1173
b) Non-summer. For billings based on meter readings during the months of
January through May and September through December.
(i) Tier 1 - for the first five hundred (500)
kilowatt hours per month, per kWh
(ii) Tier 2 - for the next five hundred (500)
kilowatt hours per month, per kWh
(iii) Tier 3 - for all additional kilowatt
hours per month, per kWh
Per kWh $0.0595
Per kWh
$0.0638
Per kWh $0.0733
4. Payment in lieu of taxes (PILOT) and franchise.
A charge of all monthly service charges billed pursuant to this
Section
6 percent
b. Air Conditioning (A/C) Time-of-useday. The discounted monthly rates for
customers with medical needs requiring air conditioning only shall be the sum of
the following charges, applied to all meter readingsenergy consumption on or
after October January 1, 20189:
1. Fixed Charge Per account
$5.81
$6.40
2. Distribution facilities charge Per kWh
$0.0197
$0.0217
3. Energy and demand charge
a) Summer. For billings based on consumption during the months of May,
June, July, August, and September
(i) On-Peak (Mon-Fri, 2 pm to 7 pm,
excluding holidays)
(ii) Off-Peak
Per kWh
$0.0428
$0.0437
Per kWh
$0.0428
$0.0437
b) Non-summer. For billings based on consumption during the months of
January through April and October through December.
-7-
(i) On-Peak (Mon-Fri, 5 pm to 9 pm,
excluding holidays)
(ii)Off-Peak
Per kWh
$0.1788
$0.1824
Per kWh
$0.0411
$0.0419
4. 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
$0.0166
$0.0183
...
(5)
a. Tiered. 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, applied to all meter readings on or after January
1, 2018, through September 30, 2018:
1. Fixed Charge Per account $5.81
2. Distribution facilities charge Per kWh $0.0257
3. Energy and demand charge
a) Summer. For billings based on meter readings during the months of
June, July and August, provided that no customer shall be billed more
than three (3) full billing cycles at the summer rate.
(i) Tier 1 - for the first five hundred
(500) kilowatt hours per month
(ii) Tier 2 - for the next five hundred
(500) kilowatt hours per month
(iii) Tier 3 - for all additional kilowatt
hours per month
Per kWh $0.0234
Per kWh $0.0298
Per kWh $0.1173
b) Non-summer. For billings based on meter readings during the months of
January through May and September through December.
(i) Tier 1 - for the first five hundred
(500) kilowatt hours per month, per
kWh
(ii) Tier 2 - for the next five hundred
(500) kilowatt hours per month, per
kWh
(iii) Tier 3 - for all additional kilowatt
hours per month, per kWh
Per kWh $0.0325
Per kWh
$0.0638
Per kWh $0.0733
4. Payment in lieu of taxes (PILOT) and franchise.
A charge based on all monthly service charges billed
pursuant to this Section
6 percent
-8-
b. Durable Medical Equipment (DME) & A/C Time-of-use-day. 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, applied to all meter readingsenergy consumption on or after October
January 1, 20189:
1. Fixed Charge Per account
$5.81
$6.40
2. Distribution facilities charge Per kWh
$0.0197
$0.0217
3. Energy and demand charge
a) Summer. For billings based on consumption during the months of May,
June, July, August, and September
(i) On-Peak (Mon-Fri, 2 pm to 7 pm,
excluding holidays)
(ii) Off-Peak
Per kWh
$0.0428
$0.0437
Per kWh
$0.0300
$0.0306
b) Non-summer. For billings based on consumption during the months of
January through April and October through December.
(i) On-Peak (Mon-Fri, 5 pm to 9 pm,
excluding holidays)
(ii) Off-Peak
Per kWh
$0.1252
$0.1277
Per kWh
$0.0288
$0.0294
4. 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
$0.0166
$0.0183
...
. . .
(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 $2.10 $2.21
. . .
(p) Net metering.
-9-
…
(5)
a. Tiered Rate - Limited Term. 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 from the
utility consumed 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, applied to all
remotemanual-read meter readings on or after January 1, 20198, through
September 30, 2018. Customers enrolled in manual meter reading services as of
August 31, 2018 shall remain on the tiered rates below until the date meter
upgrades necessary to serve such customers on time-of-day rates are completed, at
which time the time-of-day rates under subsection (b.) of this Section shall apply.
1. Distribution facilities credit Per kWh
$0.0257
$0.0283
2. Energy and demand credit Per kWh
$0.0647
$0.0660
b. Time-of-day. For customer-generators on a "time-of-day" (TOD) rate,
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
from the utility consumed by the customer-generator shall be billed at the
applicable rates under Subsection (c) of this Section. The energy produced by the
customer-generator shall be credited to the customer monthly as follows, applied
to all meter readingsgeneration returned to the grid on or after October January 1,
20189. Customers enrolled in manual meter reading services as of August 31,
2018 shall be credited based on time-of-day rates as of the date meter upgrades
necessary to serve such customers on time-of-day rates are completed.
1. Distribution facilities credit Per kWh
$0.0197
$0.0217
2. Energy and demand credit – For billings based on generation during the months of May,
June, July, August and September
a) On-Peak (Mon-Fri, 2 pm to 7 pm, excluding holidays) Per kWh $0.2015
$0.2055
b) Off-Peak Per kWh $0.0428
$0.0437
3. Energy and demand credit – For billings based on generation during the months of January
through April and October through December
a) On-Peak (Mon-Fri, 5 pm to 9 pm, excluding holidays) Per kWh $0.1788
$0.1824
-10-
b) Off-Peak Per kWh $0.0411
$0.0419
. . .
(r) Net metering—community solar projects.
. . .
(3)
a. Tiered Rate - Limited Term. Both the customer’s consumption of energy
from Fort Collins Utilitiesthe utility and interest in the production of energy that
flows into Fort Collins Utilities'the utilities’ distribution system shall be measured
on a monthly basis. The energy from Fort Collins Utilities consumed by the
customer shall be billed at the applicable rate as outlined in Subsections (c) of this
Section. The method used to measure energy produced and issue credits under
this Section shall be the same for subscriber-owned facilities and dedicated
program-managed facilities. The energy produced by the customer's portion of
the qualifying facility shall be credited to the customer monthly as follows,
applied to all remote-read meter readings on or after January 1, 20198, through
September 30, 2018. Customers enrolled in manual meter reading services as of
August 31, 2018 shall remain on the tiered rates below until the date meter
upgrades necessary to serve such customers on time-of-day rates are completed, at
which time the time-of-day rates under subsection (b.)of this Section shall apply.
1. Distribution facilities credit Per kWh
$0.0128
$0.0141
2. Energy and demand credit Per kWh
$0.0647
$0.0660
b. Time-of-day. For customer-generators on a "time-of-day" (TOD) rate, the
customer’s consumption of energy from Fort Collins Utilitiesthe utility and
interest in the production of energy that flows into Fort Collins Utilities'the
utilities’ distribution system shall be measured on a monthly basis. The energy
from the utility consumed by the customer-generator shall be billed at the
applicable rates under Subsection (c) of this Section. The method used to measure
energy produced and issue credits under this Section shall be the same for
subscriber-owned facilities and dedicated program-managed facilities. The energy
produced by the customer-generator shall be credited to the customer monthly as
follows, applied to all remote-read meter readingsgeneration returned to the grid
on or after October January 1, 20189. Customers enrolled in manual meter
reading services as of August 31, 2018 shall be credited based on time-of-day
rates as of the date meter upgrades necessary to serve such customers on time-of-
day rates are completed.
-11-
1. Distribution facilities credit Per kWh $0.0099
$0.0109
2. Energy and demand credit – For billings based on generation during the months of
May, June, July, August and September
a) On-Peak (Mon-Fri, 2 pm to 7 pm, excluding holidays) Per kWh $0.2015
$0.2055
b) Off-Peak Per kWh $0.0428
$0.0437
3. Energy and demand credit – For billings based on generation during the months of
January through April and October through December
a) On-Peak (Mon-Fri, 5 pm to 9 pm, excluding holidays) Per kWh $0.1788
$0.1824
b) Off-Peak Per kWh $0.0411
$0.0419
c. The Utilities Executive Director shall have authority to extend issuance of
credits under Subsection (3)a until December 31, 2018, as needed to comply with
requirements of power supply or purchase agreements with project owners.
Section 3. That Sections 26-465 (c), (e), (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.
(1) Tiered Rate - Limited Term. The monthly rates shall be the sum of the
following charges, applied to all remotemanual-read meter readings on or after
January 1, 20198, through September 30, 2018. Customers enrolled in manual
meter reading services as of August 31, 2018 shall remain on the tiered rates
below until the date meter upgrades necessary to serve such customers on time-of-
day rates are completed, at which time the time-of-day rates in subsection (2) of
this Section shall apply.
a. Fixed Charge Per account
$5.81
$6.40
b. Demand charge Per kW
$2.45
$2.50
c. Distribution facilities charge Per kWh $0.0229
-12-
$0.0249
d. Energy charge
1. Summer. For billings based on meter readings in the months
of June, July and August
2. Non-summer. For billings based on meter readings in the
months of January through May and September through
December
Per kWh
$0.0452
$0.0461
Per kWh
$0.0434
$0.0443
3. 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.
...
(2) Time of day. The monthly rates for this schedule shall be the sum of the
following charges, applied to all remote-read meter readingsenergy consumption
on or after October January 1, 20189. Customers enrolled in manual meter
reading services as of August 31, 2018 shall be billed based on time-of-day rates
as of the date meter upgrades necessary to serve such customers on time-of-day
rates are completed.
a. Fixed Charge Per account
$5.81
$6.40
b. Demand charge Per kW $2.45
cb. Distribution facilities charge Per kWh
$0.0257
$0.0280
dc. Energy and demand charge
1. Summer. For billings based on consumption during the months of May, June, July and August,
and September
a) On-Peak (Mon-Fri, 2 pm to 7 pm, excluding holidays) Per kWh
$0.02015
$0.2055
b) Off-Peak Per kWh
$0.0428
$0.0437
2. Non-summer. For billings based on consumption during the months of January through April
and October through December.
a) On-Peak (Mon-Fri, 5 pm to 9 pm, excluding holidays) Per kWh
$0.1788
$0.1824
b) Off-Peak Per kWh
$0.0411
$0.0419
3. The meter reading date shall generally determine the summer
season billing months; however, no customer shall be billed more than
-13-
three (3) full billing cycles at the summer rate.
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. Income-qualified assistance discount. The discount applied to the monthly charges in
“a.”, “b.”, and “c.” above for IQAP participating residential customers, as further
described in Section 26-724 of the Code.
23 percent
...
...
(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 $2.10
$2.21
(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)
a. Tiered Rate - Limited Term. 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 from the
utility consumed 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, applied to all remotemanual-read meter readings on or after January 1,
20198, through September 30, 2018. Customers enrolled in manual meter reading
Contracted standby service, this charge shall be in lieu
of the distribution facilities charge.
Per kW
$2.12
$2.23
For all metered kilowatts in excess of the contracted
amount
Per kW
$6.35
$6.67
-14-
services as of August 31, 2018 shall remain on the tiered rates below until the date
meter upgrades necessary to serve such customers on time-of-day rates are
completed, at which time the time-of-day rates in subsection (b.) of this Section
shall apply.
1. Distribution facilities credit Per kWh
$0.0257
$0.0283
2. Energy and demand credit Per kWh
$0.0647
$0.0660
b. Time-of-day. For customer-generators on a "time-of-day" (TOD) rate,
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
from the utility consumed by the customer-generator shall be billed at the
applicable rates under Subsection (c) of this Section. The energy produced by the
customer-generator shall be credited to the customer monthly as follows, applied
to all remote-read meter readingsgeneration returned to the grid on or after
October January 1, 20189. Customers enrolled in manual meter reading services
as of August 31, 2018 shall be credited based on time-of-day rates as of the date
meter upgrades necessary to serve such customers on time-of-day rates are
completed.
1. Distribution facilities credit Per kWh
$0.0257
$0.0279
2. Energy and demand credit – For billings based on generation during the months of May, June,
July, August and September
a) On-Peak (Mon-Fri, 2 pm to 7 pm, excluding holidays) Per kWh $0.2015
$0.2055
b) Off-Peak Per kWh $0.0428
$0.0437
3. Energy and demand credit – For billings based on generation during the months of January
through April and October through December
a) On-Peak (Mon-Fri, 5 pm to 9 pm, excluding holidays) Per kWh $0.1788
$0.1824
b) Off-Peak Per kWh $0.0411
$0.0419
-15-
(r) Net metering-community solar projects.
. . .
(3)
a. Tiered Rate - Limited Term. Both the customer’s consumption of energy
from Fort Collins Utilitiesthe utility and interest in the production of energy that
flows into Fort Collins Utilities'the utilities’ distribution system shall be measured
on a monthly basis. The energy from Fort Collins Utilities consumed by the
customer shall be billed at the applicable seasonal tiered rate as outlined in
Subsections (c) of this Section. The method used to measure energy produced and
issue credits under this Section shall be the same for subscriber-owned facilities
and dedicated program-managed facilities. The energy produced by the
customer's portion of the qualifying facility shall be credited to the customer
monthly as follows, applied to all remotemanual-read meter readings on or after
January 1, 20198, through September 30, 2018. Customers enrolled in manual
meter reading services as of August 31, 2018 shall remain on the tiered rates
below until the date meter upgrades necessary to serve such customers on time-of-
day rates are completed, at which time the time-of-day rates under subsection (b.)
of this Section shall apply.
a. Distribution facilities credit Per kWh
$0.0128
$0.0141
b. Energy and demand credit Per kWh
$0.0647
$0.0660
b. Time-of-day. For customer-generators on a "time-of-day" (TOD) rate, the
customer’s consumption of energy from Fort Collins Utilitiesthe utility and
interest in the production of energy that flows into Fort Collins Utilities'the
utilities’ distribution system shall be measured on a monthly basis. The energy
from the utility consumed by the customer-generator shall be billed at the
applicable rates under Subsection (c) of this Section. The method used to measure
energy produced and issue credits under this Section shall be the same for
subscriber-owned facilities and dedicated program-managed facilities. The energy
produced by the customer-generator shall be credited to the customer monthly as
follows, applied to all remote-read meter readingsgeneration returned to the grid
on or after October January 1, 20198. Customers enrolled in manual meter
reading services as of August 31, 2018 shall be credited based on time-of-day
rates as of the date meter upgrades necessary to serve such customers on time-of-
day rates are completed.
1. Distribution facilities credit Per kWh
$0.0128
$0.0141
2. Energy and demand credit – For billings based on generation during the months of May,
June, July, August and September
-16-
a) On-Peak (Mon-Fri, 2 pm to 7 pm, excluding holidays) Per kWh $0.2015
$0.2055
b) Off-Peak Per kWh $0.0428
$0.0437
3. Energy and demand credit – For billings based on generation during the months of
January through April and October through December
a) On-Peak (Mon-Fri, 5 pm to 9 pm, excluding holidays) Per kWh $0.1788
$0.1824
b) Off-Peak Per kWh $0.0411
$0.0419
Section 4. That Sections 26-466 (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.
. . .
(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 $3.61
$4.05
b. Single-phase, above two-hundred-ampere service Per account $10.65
$11.95
c. Three-phase, two-hundred-ampere service Per account $5.50
$6.17
d. Three-phase, above two-hundred-ampere service Per account $13.03
$14.62
(2) Demand charge
a. Summer. For billings based on meter readings in the months of
June, July, and August
Per kWh $0.0273
$0.0278
b. Non-summer. For billings based on meter readings in the
months of January through May and September through
December
Per kWh $0.0167
$0.0170
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 $0.0245
$0.0275
-17-
(4) Energy charge
a. Summer. For billings based on meter readings in the months of
June, July, and August
Per kWh $0.0452
$0.0461
b. Non-summer. For billings based on meter readings in the
months of January through May and September through
December
Per kWh $0.0434
$0.0443
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.
...
...
(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 $2.10
$2.21
. . .
(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 from the utility consumed 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. Energy credit for billings based on generation during the months
of June, July and August
Per kWh $0.0452
$0.0461
(r) Net metering-community solar projects.
. . .
(3) Both the customer's consumption of energy from Fort Collins Utilitiesthe
utility and interest in the production of energy that flows into Fort Collins
Utilities'the utilities’ distribution system shall be measured on a monthly basis.
The energy from Fort Collins Utilities consumed by the customer shall be billed
-18-
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:
a. Distribution facilities credit Per kWh
$0.0122
$0.0137
b. Energy and demand credit Per kWh
$0.0452
$0.0461
Section 5. That Sections 26-467 (c), (e), (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 $3.61
$4.23
b. Single-phase, above two-hundred-ampere service Per account $10.65
$12.48
c. Three-phase, two-hundred-ampere service Per account $5.50
$6.45
d. Three-phase, above two-hundred-ampere service Per account $13.03
$15.27
2. Demand charge
a. Summer. For billings based on meter readings in the months
of June, July, and August
Per kW $8.31
$8.48
b. Non-summer. For billings based on meter readings in the
months of January through May and September through
December
Per kW $4.76
$4.86
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 $0.0186
$0.0218
4. Energy charge
a. Summer. For billings based on meter readings in the months
of June, July, and August
Per kWh $0.0452
$0.0461
-19-
b. Non-summer. For billings based on meter readings in the
months of January through May and September through
December
Per kWh $0.0434
$0.0443
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.
...
...
(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 $2.10
$2.21
(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
$3.84
$4.05
For all metered kilowatts in excess of the contracted amount Per kW
$11.54
$12.16
. . .
(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 from the utility consumed 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. Energy credit for billings based on generation during the Per kWh $0.0452
-20-
months of June, July and August $0.0461
Section 6. That Sections 26-468 (c), (e) 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
$9.11
$10.70
An additional charge may be assessed if telephone
communication service is not provided by the customer.
Per account
$40.14
$47.16
(2) Coincident demand charge
a. Summer. For billings based on meter readings in the months
of June, July and August
Per kW
$11.91
$12.15
b. Non-summer. For billings based on meter readings in the
months of January through May and September through
December
Per kW
$9.08
$9.26
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 $6.27
$7.37
(4) Energy charge
a. Summer. For billings based on meter readings in the months
of June, July, and August
Per kWh $0.0452
$0.0461
b. Non-summer. For billings based on meter readings in the
months of January through May and September through
December
Per kWh $0.0434
$0.0443
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.
...
...
(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 $2.10
$2.21
-21-
(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
$4.94
$5.20
For all metered kilowatts in excess of the contracted amount Per kW
$14.82
$15.61
. . .
(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
$1.06
Metered kilowatts in excess of the contracted amount
Per kW $3.04
$3.20
(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 from the utility consumed by the
customer-generator shall be billed at the applicable rate as outlined in Subsection
-22-
(c) of this Section. The energy produced by the customer-generator shall be
credited to the customer monthly as follows:
a. Energy credit for billings based on generation during the
months of June, July and August
Per kWh $0.0452
$0.0461
Section 7. That Sections 26-469 (c), (e) 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
$15.62
$20.77
a. Additional charge for each additional metering point Per account
$9.53
$12.67
b. An additional charge may be assessed if telephone
communication service is not provided by the customer.
Per account
$40.14
$53.39
(2) Coincident demand charge
a. Summer. For billings based on meter readings in the
months of June, July and August
Per kW
$11.74
$11.97
b. Non-summer. For billings based on meter readings in the
months of January through May and September through
December
Per kW
$8.95
$9.13
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 $6.02
$8.01
b. All additional kilowatts
Per kW $3.56
$4.73
(4) Energy charge
a. Summer. For billings based on meter readings in the
months of June, July, and August
Per kWh $0.0445
$0.0454
b. Non-summer. For billings based on meter readings in the
months of January through May and September through
Per kWh $0.0427
-23-
December $0.0436
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.
...
...
(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 $2.10
$2.21
(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
$3.42
$3.59
For all metered kilowatts in excess of the contracted amount Per kW
$10.28
$10.80
. . .
(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 rates:
(1) Monthly charge.
.
Contracted backup capacity per month
Per kW $0.70
$0.74
Metered kilowatts in excess of the contracted amount
Per kW $2.11
$2.22
-24-
. .
(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 from the utility consumed 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. Energy credit for billings based on generation during the months
of June, July and August
Per kWh $0.0445
$0.0454
Section 8. That Sections 26-470 (c), (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
$35.51
$49.36
(2) Coincident demand charge
a. Summer. For billings based on meter readings in the
months of June, July and August
Per kW
$11.56
$11.79
b. Non-summer. For billings based on meter readings in the
months of January through May and September through
December
Per kW
$8.81
$8.99
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 $2.88
$4.00
(4) Energy charge
a. Summer. For billings based on meter readings in the
months of June, July, and August
Per kWh $0.0439
$0.0448
-25-
b. Non-summer. For billings based on meter readings in the
months of January through May and September through
December
Per kWh $0.0420
$0.0428
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.
...
...
(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
$2.56
$2.68
For all metered kilowatts in excess of the contracted amount Per kW
$7.68
$8.03
. . .
(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 from the utility consumed 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. Energy credit for billings based on generation during the
months of June, July and August
Per kWh $0.0439
$0.0448
Section 9. That the amendments herein are effective and shall go into effect as
follows:
-26-
a. Amended commercial schedule tiered rates (GS, GS25, GS50, GS750 &
SS) shall apply to all electricity used on or after January 1, 20182019;
b. Amended schedules of tiered rates for all other rate classes shall apply to
all bills issued on the basis of meter readings on or after January 1,
20182019;
c. Schedules of residential TOD rates (R and RD rate classes) shall apply to
all bills issued on the basis of meter readings on or after October 1, 2018.
Section 10. That Section 26-471 of the Code of the City of Fort Collins is hereby
amended to read as follows:
Sec. 26-471. - Special area floodlighting, schedule FL.
(a) Applicability. Special area floodlighting, schedule 10 shall be available within the
corporate limits of the City and the suburban fringe for outdoor area floodlighting of consumer's
property from dusk to dawn.
(b) Monthly rate. The monthly rates (including a six (6) percent charge in lieu of taxes and
franchise) are as follows:
(1) Charge per lamp, mercury vapor:
a. One hundred seventy five (175) watt $16.93 $17.78
b. Two hundred fifty (250) watt $19.94 $20.94
c. Four hundred (400) watt $26.14 $27.45
(2) Charge per lamp, high-pressure sodium:
a. Seventy (70) watt $7.15 $7.51
b. One hundred (100) watt $10.12 $10.63
c. One hundred fifty (150) watt $16.01 $16.81
d. Two hundred fifty (250) watt $20.41 $21.43
e. Four hundred (400) watt $26.96 $28.31
(3) Charge per lamp, LED:
a. Fifty-four (54) watt $7.37
b. Seventy-two (72) watt $8.57
-27-
(c) Service charge. Service charges and connection fees shall be as set forth in Subsection
26-712(b).
(d) Service rights fee in certain annexed areas. A fee for defraying the cost of acquisition of
service rights from Poudre Valley Rural Electric Association (PVREA) shall be charged for each
service in areas annexed into the City after April 22, 1989, if such area was previously served by
PVREA. The service rights fee will be collected monthly for a period of ten (10) consecutive
years following the date of acquisition by the City of electric facilities in such area from
PVREA. If service was previously provided by PVREA, the fee shall be twenty-five (25) percent
of charges for electric power service. For services that come into existence in the affected area
after date of acquisition, the fee shall be five (5) percent of charges for electric power service. In
the event that the City Council has determined that a reduction of the service rights fee is
justified in order to mitigate the economic impacts to a lot or parcel of land at the time of
annexation of said lot or parcel of land, the service rights fee charged pursuant to this Subsection
may be reduced by the City Council pursuant to a schedule set forth in the ordinance annexing
said parcel or lot. The service rights fee charged pursuant to this Subsection shall not be subject
to the charge in lieu of taxes and franchise otherwise required in this Section.
(e) Payment of charges. Due dates and delinquency procedures shall be as set forth in § 26-
713.
(f) Contract period and conditions.
(1) Those desiring floodlighting service shall sign a service contract at the electric
utility office. This contract may be terminated at the end of any billing period upon ten
(10) days' written notice to the City.
(2) The lamps shall be controlled by automatic control equipment and burning time
shall be from approximately thirty (30) minutes after sunset to approximately thirty (30)
minutes before sunrise.
(3) The customer shall notify the utility of any operational failure of the lamp. Lamp
replacements or repairs will be performed only during regular working hours.
(g) Rules and regulations. Service supplied under this schedule is subject to the terms and
conditions set forth in the electric utility rules and regulations, as approved by the City Council.
Copies may be obtained from the Utility's Customer Service Office.
Section 11. That Section 26-472 of the Code of the City of Fort Collins is hereby
amended to read as follows:
Sec. 26-472. - Traffic signal service, schedule T.
(a) Availability. The traffic signal service, schedule T, shall be available within the corporate
limits of the City.
-28-
(b) Applicability. This schedule shall be applicable only to municipal traffic signal service.
(c) Monthly rate. The monthly rates (including a six (6) percent charge in lieu of taxes and
franchise) shall be the sum of the following charges:
(d) Payment of charges. Bills for traffic signal energy consumption and equipment rental
shall be rendered by the electric utility and paid by the City at the end of each month. Monthly
billings shall be based on the inventory of completed installations at the time of billing.
Introduced, considered favorably on first reading, and ordered published this 6th day of
November, A.D. 2018, and to be presented for final passage on the 20th day of November, A.D.
2018.
__________________________________
Mayor
ATTEST:
_______________________________
City Clerk
(1) Fixed charge Per account
$73.16
$76.82
(2) Energy charge Per kWh
$0.0680
$0.0714
(3) Service extensions and signal
installations made by the utility shall
be paid for by the City General
Fund, subject to material and
installation costs at the time of
installation.
-29-
Passed and adopted on final reading on the 20th day of November, A.D. 2018.
__________________________________
Mayor
ATTEST:
_______________________________
City Clerk
-1-
ORDINANCE NO. 135, 2018
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 Fort Collins; 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 2019 reflects an increase
of approximately 2%; and
WHEREAS, the Water Board considered the proposed stormwater utility fee adjustments
for 2019 at its meeting on October 18, 2018, and recommended approval of the proposed
adjustments; and
WHEREAS, pursuant to City Code Section 26-511, the City Manager recommends the
proposed stormwater utility fee for 2019; 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.
-2-
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 $0.0043526 $0.00444 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, 2019.
Introduced, considered favorably on first reading, and ordered published this 6th day of
November, A.D. 2018, and to be presented for final passage on the 20th day of November, A.D.
2018.
__________________________________
Mayor
ATTEST:
_______________________________
City Clerk
-3-
Passed and adopted on final reading on the 20th day of November, A.D. 2018.
__________________________________
Mayor
ATTEST:
_______________________________
City Clerk
$0.2015
$0.2055
ATTACHMENT 7
$28/month
$12,423
$82,641
$16,695
DocuSign Envelope ID: F4E9F08D-4988-4ADA-8377-119606478D07
9.66 ENVIR ENHANCEMENT - 1.0 FTE Utilities: Wastewater/Water/Stormwater Water - Field Operations Manager $58,621 $54,696 00
9.69 ENVIR ENHANCEMENT - Utilities: Wastewater/Stormwater - Regulatory Water Quality Monitoring Study (bacteriological) $37,500 $37,500 00
9.72 ENVIR ENHANCEMENT - Utilities: Wastewater/Water/Stormwater - Engineering Support to Maintain Levels of Service $95,550 $95,550 00
10.19 HPG ENHANCEMENT: CAPITAL - Utilities: Asset Register and Work Order Management System $11,000 $152,000 00
10.20 HPG ENHANCEMENT: Utilities: Water/Wastewater/Stormwater Scanning As-built Plans $15,000 $0 00
10.23 HPG ENHANCEMENT: CAPITAL - Utilities: 700 Wood Street Building/Facilities $40,000 $17,500 00
11.20 SAFE ENHANCEMENT: Utilities: Stormwater - Drainage and Detention Maintaining Existing Levels of Service $40,500 $40,500 00
11.11 SAFE ENHANCEMENT: CAPITAL REPLACEMENT - Utilities: Stormwater - Castlerock Storm Sewer Evaluation and Rep $300,000 $0 00
11.12 SAFE ENHANCEMENT: CAPITAL - Utilities: Stormwater - Poudre River at Oxbow Levee $412,000 $0 00
11.13 SAFE ENHANCEMENT: CAPITAL - Utilities: Stormwater - North College Drainage Improvement District, Phase 1 $267,800 $0 00
11.14 SAFE ENHANCEMENT: CAPITAL - Utilities: Remington Street Water, Wastewater and Stormwater Improvements $412,000 $2,546,200 00
11.15 SAFE ENHANCEMENT: CAPITAL - Utilities: Stormwater - Timberline Levee (Design Only) $103,000 $0 00
11.16 SAFE ENHANCEMENT: CAPITAL - Utilities: Stormwater - Drake Levee (Design Only) $51,500 $0 00
11.17 SAFE ENHANCEMENT: CAPITAL - Utilities: Stormwater - Flood Warning System $100,000 $100,000 00
86.10 ENVIR ENHANCEMENT: Encampment Cleaning Services $80,000 $80,000 00
9.67 ENVIR ENHANCEMENT - 1.0 FTE Utilities: Wastewater/Water/Stormwater Utilities Project Coordinator $48,857 $42,529 11
9.68 ENVIR ENHANCEMENT - 1.0 FTE Utilities: Wastewater/Water/Stormwater Over hire for Engineering Director $15,616 $0 11
11.19 SAFE ENHANCEMENT: Utilities: Stormwater Outreach and Engagement Enhanced Effort $20,000 $20,000 11
11.21 SAFE ENHANCEMENT CAPITAL - Utilities: Wastewater/Water/Stormwater - Geographic Information System Program $66,600 $66,600 11
87.2 SAFE ENHANCEMENT: OEM $7,000 $7,150 11
Capital Replacement - Utilities: Stormwater - Collection System Replacement - Small
Capital Projects
% Change 9.2% -4.0% 5.4% 0.2% 3.5%
ATTACHMENT 3