Our Commitment:
Sustain Growth.
Make a Difference.
Lead the Way.
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500 Energy Lane, Dover, Delaware 19901 USA | chpk.com
2 0 2 1 A N N U A L R E P O R T
The Marlin Gas Services tractor transports pictured here are fueled by compressed natural gas (CNG), reducing greenhouse gas emissions by up to 20% compared to diesel fuel.Marlin Gas Services, a subsidiary of Chesapeake Utilities Corporation, operates a fleet of compressed natural gas (CNG), liquefied natural gas (LNG), renewable natural gas (RNG) and hydrogen transport trailers designed to provide virtual pipeline and temporary fueling solutions.Paul L. Maddock, Jr.DIRECTOR SINCE 2009 Chief Executive Officer and Manager, Palamad, LLC, Palm Beach, FloridaCalvert A. Morgan, Jr.DIRECTOR SINCE 2000Retired Director and Former Special Advisor, WSFS Financial Corporation, and Retired Director and Former Vice Chair, Wilmington Savings Fund Society (WSFS Bank), Wilmington, Delaware; Retired Chair, President & Chief Executive Officer, PNC Bank, Wilmington, DelawareDianna F. MorganDIRECTOR SINCE 2008Former Senior Vice President, Walt Disney World Co., Orlando, Florida; Past Chair of the Board of Trustees, University of Florida, Gainesville, FloridaDennis S. Hudson, IIIDIRECTOR SINCE 2009Former Executive Chair of the Board, and Chief Executive Officer, Seacoast Banking Corporation of Florida & Seacoast National Bank, Stuart, Florida COMPENSATION COMMITTEEDianna F. Morgan—CHAIRLisa G. BisacciaRonald G. Forsythe, Jr., Ph.D.Dennis S. Hudson, IIICalvert A. Morgan, Jr. CORPORATE GOVERNANCE COMMITTEECalvert A. Morgan, Jr.—CHAIRLila A. Jaber, Esq.Paul L. Maddock, Jr.Dianna F. Morgan INVESTMENT COMMITTEEJeffry M. Householder—CHAIRThomas J. BresnanThomas P. Hill, Jr.Calvert A. Morgan, Jr.John R. SchimkaitisAUDIT COMMITTEE Thomas J. Bresnan—CHAIRRonald G. Forsythe, Jr., Ph.D.Thomas P. Hill, Jr.Dennis S. Hudson, IIILila A. Jaber, Esq. DIRECTOR SINCE 2020President, Jaber Group Inc., Tallahassee, FloridaSustain Growth. Make a Difference. Lead the Way. Dear Shareholders,
Last year, as I was writing the President’s Letter for our 2020 Annual Report, I reflected on what was a
truly extraordinary year: a global pandemic, political upheaval, social unrest and economic uncertainty.
In spite of these challenges, our 2020 Annual Report theme declared that we ended the year
“Standing Strong,” and we reported yet another year of record performance. It was clear to me on that
early day in January 2021 that we likely faced another year of uncertainty, another year requiring the
Chesapeake Utilities team to pull together and overcome whatever obstacles we might encounter.
I am pleased to report we did exactly that. The challenges from 2020 continued in 2021, and we
added a few hurricanes, energy price volatility and the transition back to more typical customer billing
practices. It’s hard for me to adequately express my pride and appreciation for the focus, dedication
and hard work exemplified by our team members. As a direct result of their efforts, we kept our
workforce safe and grew diluted earnings per share from continuing operations by 12.4% in 2021, the
15th year in a row we are reporting record earnings performance.
Consistent, record performance over a long period is typically the result of a well-executed strategy.
Ours dates back to 2004 when we formally adopted a fundamental and straightforward growth
strategy that even today, continues to apply and serve our stakeholders well: Build on our solid
foundation of growing, regulated energy delivery businesses and invest in related non-
regulated businesses that provide opportunities to produce returns greater than those of
the regulated units. On the surface, that sounds fairly obvious. However, executing that strategy
requires the discipline to optimize growth in our regulated units, control costs and walk away from
deals or projects that don’t align with our strategy or financial targets. It’s not growth just to get bigger.
It is managed growth, operating an intentionally designed portfolio of regulated and non-regulated
businesses that are similar in function and frequently work together to provide creative customer
solutions and opportunities for enhanced margins.
With our energized, creative
workforce leading the way,
we believe we are in the right
place, at the right time, with
the right set of assets to
both play a meaningful role
in the transitional energy
marketplace and continue
to deliver top quartile
financial performance
for our shareholders.
3
Jeff Householder, President and CEO
Sustain Growth. Make a Difference. Lead the Way. Over a long period of time, we have built a stable business that effectively manages risk, sticks to
a time-tested strategy and consistently produces attractive results. We operate energy delivery
businesses in the mid-Atlantic and Southeast, where customer demand continues to support long-
term growth. That same combination of energy delivery businesses and locations also provides
interesting opportunities for investment in many of the lower carbon energy projects developing
across our service areas.
Every year, we participate in a process to establish a theme for our Annual Report. It’s usually as
much, or more, about signaling where we are going as it is about what we accomplished last year.
We settled on a string of phrases this year: Sustain Growth. Make a Difference. Lead the Way.
I think those statements sum up what we are doing at Chesapeake Utilities. We are laser-focused
on sustaining the historical growth of our business. We also clearly understand our responsibility
to operate safely and reliably, and to continue to support the sustainability of the communities we
serve. We want to make a difference in those communities, give back, support diversity and inclusion,
operate ethically and deliver energy products and services that help make life better. And, we want to
be a leader in navigating the transition to an affordable, responsible and cleaner energy future. With
our energized, creative workforce leading the way, we believe we are in the right place, at the right
time, with the right set of assets to both play a meaningful role in the transitional energy marketplace
and continue to deliver top quartile financial performance for our shareholders.
We are laser-focused
on sustaining the
historical growth
of our business.
4
2021 Annual Report Chesapeake Utilities Corporation Sustain Growth
As we entered the second year of the
COVID-19 pandemic in early 2021, it was
evident that many of the safety protocols and
changes to our work environment that served
us well in 2020 would continue to do so for
the months to come. It was difficult to imagine
another year of heartache, overwhelmed
hospitals and economic hardships, but we
knew our job was to continue the uninterrupted
delivery of essential energy services to the
communities we serve. At the outset of the
pandemic, we implemented our business
continuity plan, quickly moved non-field
services employees to remote work and
activated a series of health and safety
policies and protocols ranging from mask
requirements to cybersecurity upgrades.
From the first day of 2021, we understood that
we would need to sustain those practices into
the coming year and that many would likely
become permanent.
What also became clear was that the pace of
change was accelerating even beyond what
we experienced in 2020. Of course, it’s not
just the pandemic. Across the country, we are
addressing long overdue issues around racial
and gender inequality, and finding inclusive
seats at the table for all points of view. Political
division leads to business concerns about
uncertain regulatory and tax policies.
Escalating calls for climate change action are
fostering the transition of the energy industry
to lower-carbon products.
It is within the context of this hastening
change that I met with groups of Chesapeake
Utilities employees for the past two years,
delivering a simple message that speaks
directly to our strategy to Sustain Growth.
We have been focused on answering the same
three questions every day.
First, how do we best position ourselves
to address the risks and execute on the
opportunities that emerge in an evolving
market environment, without sacrificing
the entrepreneurial, disciplined culture
that has directed our historic growth?
Second, what do we need to do to
continue to meet the growth and
environmental, social and governance
(ESG) expectations of our investors?
Third, what steps do we need to take
internally to continue our record levels
of growth over the coming years?
We have been successfully answering these
questions and steadily and strategically
moving our Company down a path that gives
us a long runway of future sustainable growth.
In our business, earnings growth is highly
correlated to the effective deployment of
margin-generating capital. In 2018, we issued
guidance to investors projecting total capital
expenditures in the range of $750 million to
$1 billion over the five-year period 2018-2022.
By the end of 2020, we knew that we would
reach the low end of our guidance range a year
early. In February 2021, we updated and
expanded our capital guidance for the period
2021-2025, again at $750 million to $1 billion.
We are off to a good start toward achieving the
new capital guidance range. Our capital
investment for 2021 totaled $228 million, the
second-highest total in our history, eclipsed
only by our capital spend in 2018, which
included $65 million for hurricane restoration
costs in Florida.
Our capital investments are generating
significant increases in margin and earnings.
In 2021, our adjusted gross margin was
approximately $33 million above 2020 levels.
5
Sustain Growth. Make a Difference. Lead the Way. We achieved this record margin growth in a year with weather that proved milder than normal and
with the continuing economic downturn from COVID-19. I am also pleased to report that diluted
earnings per share from continuing operations for 2021 totaled $4.73, a 12.4% increase over 2020.
While our investment, margin growth and earnings per share results were impressive, they are by no
means the only measure of our long-term performance. We surpassed several additional financial
milestones in 2021. Let me highlight a few of these notable and record-breaking accomplishments:
Our net income increased by $12 million in
2021 to $83.5 million, a 16.7% increase over 2020.
Since 2015, we have more than doubled our
net income.
Our dividend per share increased an average of
9.5% per year since 2017. Over the past 10 years,
our dividend per share has more than doubled.
Our dividend payment to investors increased
for the 18th year in a row in 2021.
Chesapeake Utilities has paid a dividend to
shareholders for 61 consecutive years.
The Company’s strong earnings performance
enabled our Board of Directors to increase
the annualized dividend per share by
9.1% to $1.92 in May of 2021.
Our Total Shareholder Return (TSR) was
37% in 2021, exceeding the S&P 500
Index. We have achieved industry top quartile
TSR for the past one-, three-, five-, 10- and
20-year periods.
For the first time, in 2021, our total assets
exceeded $2 billion. Our total book
capitalization (including short-term debt) has
increased 94% over the past five years.
Our balance sheet remains strong; our capital structure
was approximately 50% equity as a percentage of
total capitalization (including short-term debt) as we
finished 2021, even after completing the acquisition of
the Diversified Energy propane assets in late December.
Our strategy to achieve a consolidated Return on Equity
(ROE) above approved regulated returns continues to
deliver results. We have consistently exceeded 11% ROE
each year since 2005. Our 2021 ROE was 11.3%,
which is especially noteworthy given that we have raised
over $112 million in new equity over the past two years.
Financial Highlights
(Dollars in thousands, except per share data)
Adjusted Gross Margin*
Operating Income from Continuing Operations
Income from Continuing Operations
Net Income
Diluted Earnings Per Share:
From Continuing Operations
Consolidated
Annualized Dividends Per Share
Total Assets
Stockholders’ Equity
Other
Employees
Shares Outstanding at Year End
Average Distribution Customers
2021
2020
2021/2020
% Change
2019
2020/2019
% Change
$
$
$
$
$
$
$
383,017
$ 350,260
131,112
83,467
83,466
4.73
4.73
1.92
$
$
$
$
$
$
112,723
70,642
71,498
4.21
4.26
1.76
$ 2,114,869
$ 1,932,487
$
774,130
$
697,085
1,007
17,655,410
287,314
947
17,461,841
277,580
9%
16%
18%
17%
12%
11%
9%
9%
11%
6%
1%
4%
$
$
$
$
$
$
$
$
$
325,104
106,285
61,100
65,153
3.72
3.96
1.62
1,783,198
561,577
955
16,403,776
255,623
8%
6%
16%
10%
13%
8%
9%
8%
24%
-1%
6%
9%
*Adjusted Gross Margin is a non-GAAP measure. A reconciliation from GAAP Gross Margin to Adjusted Gross Margin is included in this annual report.
6
2021 Annual Report Chesapeake Utilities Corporation
Diluted Earnings Per Share from Continuing Operations
Diluted Earnings Per Share from
Continuing Operations
Average Return on Equity from Continuing Operations
Average Return on Equity from
Continuing Operations
.
3
7
4
$
1
2
.
4
$
.
2
7
3
$
.
7
4
3
$
.
7
7
2
$
9
8
2
$
.
$5.00
$4.50
$4.00
$3.50
$3.00
$2.50
$2.00
$1.50
$1.00
$0.50
13.5%
13.0%
12.5%
12.0%
11.5%
11.0%
10.5%
10.0%
%
0
3
1
.
%
3
.
1
1
%
3
.
1
1
%
5
.
1
1
%
3
.
1
1
%
0
.
1
1
2016
2017
2018
2019
2020
2021
2016
2017
2018
2019
2020
2021
Annualized Dividends Per Share
Annual Capital Expenditures
Annualized Dividends Per Share
Annual Capital Expenditures
$2.50
$2.00
$1.50
$1.00
$0.50
$-
2
9
.
1
$
6
7
.
1
$
2
6
.
1
$
8
4
.
1
$
0
3
.
1
$
2
2
.
1
$
$300,000
$250,000
$200,000
$150,000
$100,000
$50,000
$-
2016
2017
2018
2019
2020
2021
2016
2017
2018
2019
2020
2021
40%
35%
30%
25%
20%
15%
10%
5%
0%
Capital Expenditures Excluding Acquisitions
Acquisitions
Cap Ex / Total Cap
Average Annualized Shareholder Return
Average Annualized Shareholder Return
(For periods ending Dec. 31, 2021)
%
7
3
40%
35%
30%
25%
20%
15%
10%
5%
0%
%
4
2
%
9
1
%
0
2
%
6
1
1 Year
3 Year
5 Year
10 Year
20 Year
CPK
Peer 75th Percentile
Peer Median
Dow Jones Utilities Index
S&P 500
7
Sustain Growth. Make a Difference. Lead the Way. 4 TRANSFORMATION
OBJECTIVES
Simplification
Standardization
Collaboration
Automation
8
2021 Annual Report Chesapeake Utilities Corporation I spend a good deal of time thinking about
how to Sustain Growth at our Company,
considering the attributes that have driven our
performance for so many years. I always come
back to the same two things. First, you need
great people to build a great company. The
Chesapeake Utilities workforce is characterized
by people who care about making life better for
our customers and communities. It’s a workforce
full of ideas and driven to look for and execute
opportunities for growth that others might
miss. It’s a workforce that never gives up.
In addition to having great people, a company
must be intentional about sustaining growth.
That’s not easy to do year after year.
It requires establishing and maintaining a
culture that cultivates and rewards creative,
entrepreneurial thinking. One of the many
reasons our non-regulated businesses are
essential to our strategy is they operate in a
competitive, ever-changing market
environment where growth demands speed
and imagination. Properly channeled, those
characteristics also help drive our regulated
business growth. The challenge, of course, is
to promote an idea-generating, can-do,
never-give-up culture while at the same time
continuing the planning exercises, processes
and controls that are the hallmarks of our
long-standing organizational discipline.
Over the years, we have established and
continuously improved the governance of our
growth objectives. We have a robust, Board-
level, strategic growth planning process that
reviews and assesses likely market environment
scenarios as we chart a course forward.
Our enterprise risk management process
engages our entire management team in
regular assessments of business and
operational risk and mitigation strategies, also
with Board oversight and input. Our business
development team is focused on five platforms
for growth designed to optimize our existing
businesses, selectively expand our gas
transmission and propane businesses in
receptive markets and pursue investments in
renewable and sustainable energy projects.
As project or acquisition investment
opportunities develop, we employ a
comprehensive capital review process to
assess the strategic fit, financial performance,
regulatory implications and operational
requirements before any commitment.
Significant growth, especially if it involves
expanding into new service areas or investing
in non-traditional projects such as renewable
natural gas (RNG), requires us to evolve
the skills of our people, our processes and
technology. In 2019, we launched a business
transformation initiative to ensure our internal
capabilities keep pace with our growth.
We restructured the management of our
business units based on function rather than
geographic location. Our finance, accounting
and legal teams have become versed in the
transaction, operating and governance
structures that characterize many of the
emerging sustainable energy opportunities.
Throughout our units, teams are hard at
work collaborating on policy and process
standardization. The change management
practices we adopted are ensuring enhanced
communication and input as we continue
our transformation. In addition, we are
implementing a five-year technology plan
to replace or upgrade customer service,
communications, financial and operations
technology platforms.
5 PLATFORMS
FOR GROWTH
Organic Growth
Gas Transmission
Propane
Marlin Gas Services
Business
Renewable/Sustainable
Investments
9
Sustain Growth. Make a Difference. Lead the Way. While our business transformation initiative
was not specifically directed toward cost
reduction, the operational standardization
and technology enhancements are resulting
in efficiencies and expense savings. Over the
past three years, we have seen a steady
improvement in the percentage of gross
margin making it to our bottom line. In 2018,
total operations and maintenance expenses
were 49% of adjusted gross margin. For 2021,
these same expenses represented only 43%
of adjusted gross margin, the lowest level in
more than 10 years.
We continue to find opportunities to grow our
traditional natural gas, propane and electric
businesses, even as we look to increase our
renewable energy portfolio. Customer growth
in our Delmarva and Florida natural gas
distribution service territories continues to
accelerate at levels two to three times above
the national average customer growth rate.
Our significant natural gas distribution
investments in 2021 reflect the strong
customer interest in natural gas service in
residential and non-residential markets.
To support this growth, we continue to expand
our upstream gas transmission systems.
In 2021, Eastern Shore Natural Gas completed
the $45 million Del-Mar Energy Pathway
transmission expansion project, bringing
natural gas to Somerset County, Maryland, for
the first time. The expansion will support direct
service to large customers, displacing fuel oil
or wood chips as energy sources and our
related distribution expansions to serve
communities. Our electric business in Florida is
also experiencing solid customer growth. We
are in the midst of several system upgrades; we
recently replaced the first of three transformers
on our 138-69kV transmission system serving
Amelia Island and have additional investments
in system storm hardening authorized by
regulators scheduled in 2022.
Our non-regulated businesses continue to
contribute to our earnings growth and service
area expansion. For the fourth year in a row,
we closed a significant propane acquisition.
The latest acquisition of assets from Diversified
Energy Company extends our propane
operations into North and South Carolina and
further fills in our Eastern Seaboard footprint.
The transaction adds approximately 19,000
new customers and 10 million retail gallons in
areas with excellent potential for additional
expansion. The Carolinas also present
attractive opportunities for our Marlin
Gas Services virtual pipeline business.
Marlin continued in 2021 to add to its mobile
energy transport capabilities. In addition to
our compressed natural gas (CNG) transport
equipment, we added liquefied natural gas
(LNG) and hydrogen transport capabilities.
Marlin also will soon have compression
equipment to support pipeline methane
capture. Our Eight Flags Energy combined
heat and power (CHP) plant completed another
great year, sustaining an operational availability
of over 96% for the past five years. More
impressively, we have completed five
consecutive years of operation at the Eight
Flags CHP plant with zero safety incidents.
10
2021 Annual Report Chesapeake Utilities Corporation Make a Difference
Years ago, when I was taking business and
economics classes, we learned about profit
and loss, but not as much about a corporation’s
broader obligations to society. There were
certainly expectations of employing ethical
practices, and most companies could be
deemed good corporate citizens through
their charitable and community support.
The growing influence of ESG investing has
brought into sharp focus increasing
expectations that corporate success should
be defined by broader measurements than
financial performance alone.
We are fortunate at Chesapeake Utilities to
have a long history of environmental stewardship,
community support and award-winning
governance practices, and we’re committed to
doing the work that makes us better, every
day. We have built a solid ESG foundation over
many years, and we have both the will and the
resources to take a leadership position in
community sustainability and our collective
transition to a lower-carbon energy future.
OUR STRONG
CORPORATE
GOVERNANCE
In 2021, we received Ethical Boardroom’s
Award for Best Corporate Governance
in the Utilities Sector in North America.
This award recognizes our commitment
to integrity, accountability and doing
the right thing. The collaboration of our
team, in coordination with the oversight
of our Board and its committees, is
reflected throughout our disciplined
approach to governance matters and
our decision-making process.
Many Chesapeake Utilities success stories
begin with a commitment by our employees to
accept a challenge, set a target and drive for
results. Elevating our ESG expectations is no
different. Our internal emission reductions,
sustainable energy projects, community
leadership and good corporate governance
depend on employee commitments to Make a
Difference. We recognize that the evolving
market environment influences our strategy
and operating practices. Our future growth
performance is inextricably linked to ensuring
that employees across our Company
understand where we are going and why.
We want our employees to find and carry
forward a clear personal connection to our
strategic objectives, including our ESG goals.
We want every employee to understand the
contributions of their job toward achieving
those objectives.
Our leadership team, with Board concurrence
and assistance from a respected global
analytics and consulting organization, initiated
a companywide employee engagement
process in late 2020. Action steps have
included increased communications on
strategy, ESG and a variety of cultural issues,
including the post-pandemic work environment.
We’ve conducted surveys and employee focus
groups to better understand the steps we need
to take to maintain an engaged workforce that
is committed to our plan.
One of the first issues we tackled was refreshing
our mission, vision and values statements.
It had been well over a decade since we last
addressed these statements. Over several
months, we engaged in virtual employee
meetings using the statement refresh as a way
to discuss climate change, social unrest, hybrid
work, strategic growth, safety practices and a
multitude of other issues. At the end of this
discussion and input process, we landed on the
statements you see on the following page of this
Annual Report.
11
Sustain Growth. Make a Difference. Lead the Way. MISSION
We deliver energy that makes life better for
the people and communities we serve.
VISION
We will be a leader in delivering energy that
contributes to a sustainable future.
VALUES
We Care.
Put people first. Keep them safe. Build trusting relationships.
Foster a culture of equity, diversity and inclusion. Make a
meaningful difference everywhere we live and work.
We act with Integrity.
Tell the truth. Ensure moral and ethical principles drive our
decision-making. Do the right thing even when no one is watching.
We are committed to Excellence.
Achieve great things together. Hold each other accountable to
do the work that makes us better, every day. Never give up.
I think the following excerpt from our inaugural Sustainability Report, published on chpk.com in 2022,
provides an overview of how we Make a Difference for our employees, customers and communities
we serve, and it best summarizes our experience in updating our mission, vision and values.
“Passion and enthusiasm from our employees was evident as we worked to refine these statements.
Three themes resonated across our organization:
Overwhelmingly, our mission should reflect that
delivering energy that improves the lives of the
people and the communities where we live and work
continues to be the top priority for our Company.
Our vision statement must express that we would be
a Leader, not just a participant, in shaping the future
of lower-carbon energy.
“We Care” needed to remain a fundamental
Chesapeake Utilities value.
While our mission, vision and values statements were not expressly intended to address ESG
imperatives, they concisely and publicly convey our focus on environmental sustainability,
corporate citizenship and good governance.”
12
2021 Annual Report Chesapeake Utilities Corporation We want our employees to
find and carry forward a clear
personal connection to our
strategic objectives, including
our ESG goals. We want every
employee to understand the
contributions of their job toward
achieving those objectives.
13
Sustain Growth. Make a Difference. Lead the Way. Lead the Way
As we gathered employee input while
developing our new vision statement, our
discussions centered on where we’re going as
a Company and what the future could bring.
These wide-ranging conversations touched on
many topics including safe operations,
employee diversity, climate change, our
community obligations and our growth
opportunities. We quickly determined that our
forward-looking vision should keep us focused
on the energy delivery business and that we
want to be clear about our interests in
promoting a sustainable future. Several of our
early drafts included language such as “we
want to advance;” “we want to play a role in;”
or “we want to make a meaningful difference.”
To the credit of our team members, the
input we received was loud and clear.
Those statements did not adequately depict
our intention. Our employees said, “We want
our energy delivery business to be a leader,
not just a participant, in contributing to a
sustainable future.”
Important parts of our discussions focused on
raising the bar on employee and system safety.
We are on a mission to drive our safety
performance to industry-leading standards.
Our Pipeline Safety Management System is in
development and will be operational in 2022.
The Safety Town training center we
constructed at our Dover, Delaware,
operations center went into full service in 2021,
and we will begin construction on a Florida
Safety Town in 2022. Also, in 2021, we initiated
a distribution system damage prevention
program. Third-party excavations are the
leading cause of line breaks on our systems;
reducing excavation damage through this
program will improve safety and lower
methane escapes to the atmosphere.
We hold the strong belief that no leadership
position has credibility without a commitment
to workforce equity, diversity and inclusion
(EDI). We made significant progress in 2021 on
our EDI journey. I mentioned earlier that the
long-term success of our Company depends
on the ideas of our people. Encouraging a
workforce with people of diverse backgrounds
in a work environment that is free from
discrimination or harassment is a fundamental
Chesapeake Utilities commitment. Our EDI
Council is sponsored by a rotating senior-level
officer, meets monthly and reports directly
to the CEO. The Council is active in
recommending policy and program initiatives,
working with business units on employee
recruitment and development and supporting
our employee resource groups. Our Board of
Directors has an active interest in our EDI
strategy and progress, including our recruiting,
talent development and diversity metrics.
At year-end 2021, women represented 33.1%
of our total workforce and minorities 23.5%.
Our Board also added its third female director
in 2021.
As the world pursues lower-carbon energy,
we see opportunities in both our existing and
future service areas to participate in projects
that address climate change. Chesapeake
Utilities is in a position to support the
development of these projects with our existing
pipeline, truck transport and electric assets
and experience. We also see substantial
investment potential that will provide years of
capital deployment in environmentally
responsible projects closely related to our
current energy delivery businesses.
14
2021 Annual Report Chesapeake Utilities Corporation We will be a leader
in delivering energy
that contributes to a
sustainable future.
We have focused on waste-to-energy projects in our service areas that address a fundamental waste
management environmental issue. These projects produce RNG as a byproduct of the processing of
waste materials. The RNG is important to the economic viability of waste-to-energy projects, but we
target projects that help address local environmental concerns. In our mid-Atlantic, Ohio and Southeast
service areas, we identified a number of agricultural and landfill waste sources. Processing the waste
into RNG or capturing the landfill methane will result in lower greenhouse gas release and provide a
non-fossil, renewable source of gas. These projects provide additional opportunities for our business
units. Some poultry waste energy production facilities will require conventional natural gas or propane
to dry the organic fertilizer produced from waste processing. The larger-scale facilities have significant
electricity needs that can best be supplied by solar photovoltaic or CHP generation; our electric unit
has experience with both. RNG production facilities need to transport their RNG to a gas transmission
or distribution system, providing opportunities for our pipeline or Marlin Gas Services CNG transport
businesses. We are working both independently and with project developers on several opportunities.
Our sustainable energy interests extend beyond waste-to-energy projects. We are blending hydrogen
and natural gas to operate our Eight Flags CHP generating turbine on Amelia Island, Florida. Our intent
is to demonstrate that hydrogen is a viable emission reduction option for industrial gas users on our
transmission and distribution systems. Our AutoGas business continues to convert hundreds of diesel
fuel school buses, delivery trucks and other fleet vehicles to a cleaner fuel. In partnership with Atlanta
Gas Light, a subsidiary of Southern Company Gas, we constructed the largest CNG vehicle fueling
station on the East Coast, just outside the Port of Savannah in Georgia. The station will go into service
in the first part of 2022 and will offer an RNG-sourced CNG fueling option for trucks and other vehicles
serving the Port.
It’s been another great year for Chesapeake Utilities, our employees, customers, investors and
other stakeholders. We see a long runway ahead for our traditional natural gas, propane and electric
businesses. Customers see the practicality, reliability and affordability of the energy we deliver.
Our system expansions are contributing to the reduction of greenhouse gas (GHG) emissions through
the displacement of higher carbon fuels. As we bring sustainable energy projects online, we continue
to make a difference for our customers and the planet. Our unique combination of assets, capabilities
and financial strength puts us in the right position to help meet the growing demand for clean energy
and continue to deliver top-quartile value for our shareholders. We are committed to Lead the Way.
We appreciate your interest in our great Company.
Jeff Householder
President and Chief Executive Officer
15
Sustain Growth. Make a Difference. Lead the Way. UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 10-K
(Mark One)
☒ ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
For the Fiscal Year Ended: December 31, 2021
□ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
Commission File Number: 001-11590
CHESAPEAKE UTILITIES CORPORATION
(Exact name of registrant as specified in its charter)
State of Delaware
(State or other jurisdiction of
incorporation or organization)
51-0064146
(I.R.S. Employer
Identification No.)
909 Silver Lake Boulevard, Dover, Delaware 19904
(Address of principal executive offices, including zip code)
302-734-6799
(Registrant’s telephone number, including area code)
Securities registered pursuant to Section 12(b) of the Act:
Title of each class
Common Stock—par value per share $0.4867
Trading Symbol
CPK
Name of each exchange on which registered
New York Stock Exchange, Inc.
Securities registered pursuant to Section 12(g) of the Act:
None
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act. Yes ☒ No □
Indicate by check mark if the registrant is not required to file reports pursuant to Section 13 or Section 15(d) of the Act. Yes □ No ☒
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15 (d) of the Securities Exchange Act of 1934 during the
preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past
90 days. Yes ☒ No □
Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T
(§ 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No □
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth
company. See the definitions of ‘‘large accelerated filer,’’ ‘‘accelerated filer,’’ ‘‘smaller reporting company,’’ and ″emerging growth company″ in Rule 12b-2 of the
Exchange Act.
Large accelerated filer
Non-accelerated filer
☒
□
Accelerated filer
Smaller reporting company
Emerging growth company
□
□
□
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised
financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. □
Indicate by a check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Act). Yes □ No ☒
Indicate by check mark whether the registrant has filed a report on and attestation to its management’s assessment of the effectiveness of its internal control over financial
reporting under Section 404(b) of the Sarbanes-Oxley Act (15 U.S.C. 7262(b)) by the registered public accounting firm that prepared or issued its audit report. ☒
The aggregate market value of the common shares held by non-affiliates of Chesapeake Utilities Corporation as of June 30, 2021, the last business day of its most recently
completed second fiscal quarter, based on the last sale price on that date, as reported by the New York Stock Exchange, was approximately $2.1 billion.
The number of shares of Chesapeake Utilities Corporation’s common stock outstanding as of February 18, 2022 was 17,657,537
Portions of the Chesapeake Utilities Corporation Proxy Statement for the 2022 Annual Meeting of Shareholders are incorporated by reference in Part II and Part III hereof.
DOCUMENTS INCORPORATED BY REFERENCE
CHESAPEAKE UTILITIES CORPORATION
FORM 10-K
YEAR ENDED DECEMBER 31, 2021
TABLE OF CONTENTS
Part I
Item 1. Business
Item 1A. Risk Factors
Item 1B. Unresolved Staff Comments
Item 2. Properties
Item 3. Legal Proceedings
Item 4. Mine Safety Disclosures
Part II
Item 5. Market for the Registrant’s Common Equity, Related Stockholder Matters and Issuer
Purchases of Equity Securities
Item 6. Selected Financial Data
Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations
Item 7A. Quantitative and Qualitative Disclosures About Market Risk
Item 8. Financial Statements and Supplementary Data
Item 9. Changes In and Disagreements With Accountants on Accounting and Financial Disclosure
Item 9A. Controls and Procedures
Item 9B. Other Information
Part III
Item 10. Directors, Executive Officers of the Registrant and Corporate Governance
Item 11. Executive Compensation
Item 12. Security Ownership of Certain Beneficial Owners and Management and Related
Stockholder Matters
Item 13. Certain Relationships and Related Transactions, and Director Independence
Item 14. Principal Accounting Fees and Services
Part IV
Item 15. Exhibits, Financial Statement Schedules
Item 16. Form 10-K Summary
Signatures
Page
3
14
23
23
23
24
24
24
24
27
27
51
54
111
111
112
112
112
112
112
112
112
112
113
119
119
GLOSSARY OF DEFINITIONS
ASC: Accounting Standards Codification issued by the FASB
Adjusted Gross Margin: a non-GAAP measure calculated by deducting the purchased cost of natural gas, propane and electricity
and the cost of labor spent on direct revenue-producing activities from operating revenues. The costs included in Adjusted Gross
Margin exclude depreciation and amortization and certain costs presented in operations and maintenance expenses in accordance
with regulatory requirements
Aspire Energy: Aspire Energy of Ohio, LLC, a wholly-owned subsidiary of Chesapeake Utilities
Aspire Energy Express: Aspire Energy Express, LLC, a wholly-owned subsidiary of Chesapeake Utilities
ASU: Accounting Standards Update issued by the FASB
ATM: At-the-market
Boulden: Boulden, Inc., an entity from whom we acquired certain propane operating assets
CARES Act: Coronavirus Aid, Relief, and Economic Security Act
CDC: U.S. Centers for Disease Control and Prevention
CDD: Cooling Degree-Day
CFG: Chesapeake Utilities' Central Florida Gas division
CGS: Community Gas Systems
Chesapeake or Chesapeake Utilities: Chesapeake Utilities Corporation, its divisions and subsidiaries, as appropriate in the
context of the disclosure
CHP: Combined Heat and Power Plant
Columbia Gas: Columbia Gas Transmission, LLC
Company: Chesapeake Utilities Corporation, its divisions and subsidiaries, as appropriate in the context of the disclosure
COVID-19: An infectious disease caused by a discovered coronavirus
CNG: Compressed natural gas
Degree-day: A degree-day is the measure of the variation in the weather based on the extent to which the average daily
temperature (from 10:00 am to 10:00 am) falls above (CDD) or below (HDD) 65 degrees Fahrenheit
Delmarva Peninsula: A peninsula on the east coast of the U. S. occupied by Delaware and portions of Maryland and Virginia
Diversified Energy: Diversified Energy Company an entity from whom we acquired certain propane operating assets in North
Carolina, South Carolina, Virginia, and Pennsylvania
DRIP: Dividend Reinvestment and Direct Stock Purchase Plan
Dt(s): Dekatherm(s), which is a natural gas unit of measurement that includes a standard measure for heating value
Dts/d: Dekatherms per day
Eastern Shore: Eastern Shore Natural Gas Company, a wholly-owned subsidiary of Chesapeake Utilities
Eight Flags: Eight Flags Energy, LLC, a subsidiary of Chesapeake OnSight Services, LLC
Elkton Gas: Elkton Gas Company, a wholly-owned subsidiary of Chesapeake Utilities
EDI: Equity Diversity and Inclusion
Escambia Meter Station: A natural gas metering station owned by Peninsula Pipeline Company located in Escambia County,
Florida
ESG: Environmental, Social and Governance
FASB: Financial Accounting Standards Board
FERC: Federal Energy Regulatory Commission
FGT: Florida Gas Transmission Company
Flo-gas: Flo-gas Corporation, a wholly-owned subsidiary of FPU
Florida OPC: The Office of Public Counsel, an agency established by the Florida legislature who advocates on behalf of Florida's
utility consumers prior to actions or rule changes
FPU: Florida Public Utilities Company, a wholly-owned subsidiary of Chesapeake Utilities
GAAP: Generally Accepted Accounting Principles
Guernsey Power Station: Guernsey Power Station, LLC, a partner with Aspire Energy Express in the construction of a power
generation facility in Ohio.
GRIP: Gas Reliability Infrastructure Program
Gross Margin: a term under U.S. GAAP which is the excess of sales over costs of goods sold
Gulfstream: Gulfstream Natural Gas System, LLC, an unaffiliated pipeline network that supplies natural gas to FPU
HDD: Heating Degree Day
LNG: Liquefied Natural Gas
Marlin Gas Services: Marlin Gas Services, LLC, a wholly-owned subsidiary of Chesapeake Utilities
MetLife: MetLife Investment Advisors, an institutional debt investment management firm, with which we have previously issued
Senior Notes and which is a party to the current MetLife Shelf Agreement, as amended
MGP: Manufactured gas plant, which is a site where coal was previously used to manufacture gaseous fuel for industrial,
commercial and residential use
MW: Megawatt, which is a unit of measurement for electric power or capacity
NOL: Net operating losses
NYL: New York Life Investors LLC, an institutional debt investment management firm, with which Chesapeake Utilities entered
into a Shelf Agreement and issued Shelf Notes
Peninsula Pipeline: Peninsula Pipeline Company, Inc., a wholly-owned subsidiary of Chesapeake Utilities
Peoples Gas: Peoples Gas System, an Emera Incorporated subsidiary
PESCO: Peninsula Energy Services Company, Inc., an inactive wholly-owned subsidiary of Chesapeake Utilities
Prudential: Prudential Investment Management Inc., an institutional investment management firm, with which Chesapeake
Utilities entered into a previous Shelf Agreement and issued Shelf Notes
PSC: Public Service Commission, which is the state agency that regulates utility rates and/or services in certain of our
jurisdictions
Revolver: Our $400.0 million unsecured revolving credit facility with certain lenders
RNG: Renewable natural gas
Sandpiper Energy: Sandpiper Energy, Inc., a wholly-owned subsidiary of Chesapeake Utilities
SEC: Securities and Exchange Commission
Senior Notes: Our unsecured long-term debt issued primarily to insurance companies on various dates
Sharp: Sharp Energy, Inc., a wholly-owned subsidiary of Chesapeake Utilities
Shelf Agreement: An agreement entered into by Chesapeake Utilities and a counterparty pursuant to which Chesapeake
Utilities may request that the counterparty purchase our unsecured senior debt with a fixed interest rate and a maturity date not
to exceed 20 years from the date of issuance
Shelf Notes: Unsecured senior promissory notes issuable under the Shelf Agreement executed with various counterparties
SICP: 2013 Stock and Incentive Compensation Plan
TCJA: Tax Cuts and Jobs Act enacted on December 22, 2017
TETLP: Texas Eastern Transmission, LP, an interstate pipeline interconnected with Eastern Shore's pipeline
Transco: Transcontinental Gas Pipe Line Company, LLC
Uncollateralized Senior Notes: Our unsecured long-term debt issued primarily to insurance companies on various dates
U.S.: The United States of America
Western Natural Gas: Western Natural Gas Company, an entity from whom we acquired certain propane operating assets in
Jacksonville, Florida and the surrounding communities
Notes to the Consolidated Financial Statements
PART I
References in this document to “Chesapeake,” “Chesapeake Utilities,” the “Company,” “we,” “us” and “our” mean Chesapeake
Utilities Corporation, its divisions and/or its subsidiaries, as appropriate in the context of the disclosure.
Safe Harbor for Forward-Looking Statements
We make statements in this Annual Report on Form 10-K (this "Annual Report") that do not directly or exclusively relate to
historical facts. Such statements are “forward-looking statements” within the meaning of Section 27A of the Securities Act of
1933, as amended, Section 21E of the Securities Exchange Act of 1934, as amended, and the Private Securities Litigation Reform
Act of 1995. One can typically identify forward-looking statements by the use of forward-looking words, such as “project,”
“believe,” “expect,” “anticipate,” “intend,” “plan,” “estimate,” “continue,” “potential,” “forecast” or other similar words, or future
or conditional verbs such as “may,” “will,” “should,” “would” or “could.” These statements represent our intentions, plans,
expectations, assumptions and beliefs about future financial performance, business strategy, projected plans and objectives of the
Company. Forward-looking statements speak only as of the date they are made or as of the date indicated and we do not undertake
any obligation to update forward-looking statements as a result of new information, future events or otherwise. These statements
are subject to many risks and uncertainties. In addition to the risk factors described under Item 1A, Risk Factors, the following
important factors, among others, could cause actual future results to differ materially from those expressed in the forward-looking
statements:
•
•
•
•
•
•
•
•
•
•
•
•
•
•
•
•
•
•
•
•
•
state and federal legislative and regulatory initiatives that affect cost and investment recovery, have an impact on rate
structures, and affect the speed and the degree to which competition enters the electric and natural gas industries;
the outcomes of regulatory, environmental and legal matters, including whether pending matters are resolved within
current estimates and whether the related costs are adequately covered by insurance or recoverable in rates;
the impact of climate change, including the impact of greenhouse gas emissions or other legislation or regulations intended
to address climate change;
the impact of significant changes to current tax regulations and rates;
the timing of certification authorizations associated with new capital projects and the ability to construct facilities at or
below estimated costs;
changes in environmental and other laws and regulations to which we are subject and environmental conditions of property
that we now, or may in the future, own or operate;
possible increased federal, state and local regulation of the safety of our operations;
the inherent hazards and risks involved in transporting and distributing natural gas, electricity and propane;
the economy in our service territories or markets, the nation, and worldwide, including the impact of economic conditions
(which we do not control) on demand for natural gas, electricity, propane or other fuels;
risks related to cyber-attacks or cyber-terrorism that could disrupt our business operations or result in failure of information
technology systems or result in the loss or exposure of confidential or sensitive customer, employee or Company
information;
adverse weather conditions, including the effects of hurricanes, ice storms and other damaging weather events;
customers' preferred energy sources;
industrial, commercial and residential growth or contraction in our markets or service territories;
the effect of competition on our businesses from other energy suppliers and alternative forms of energy;
the timing and extent of changes in commodity prices and interest rates;
the effect of spot, forward and future market prices on our various energy businesses;
the extent of our success in connecting natural gas and electric supplies to our transmission systems, establishing and
maintaining key supply sources, and expanding natural gas and electric markets;
the creditworthiness of counterparties with which we are engaged in transactions;
the capital-intensive nature of our regulated energy businesses;
our ability to access the credit and capital markets to execute our business strategy, including our ability to obtain financing
on favorable terms, which can be affected by various factors, including credit ratings and general economic conditions;
the ability to successfully execute, manage and integrate a merger, acquisition or divestiture of assets or businesses and
the related regulatory or other conditions associated with the merger, acquisition or divestiture;
Chesapeake Utilities Corporation 2021 Form 10-K Page 1
•
•
•
•
•
the impact on our costs and funding obligations, under our pension and other post-retirement benefit plans, of potential
downturns in the financial markets, lower discount rates, and costs associated with health care legislation and regulation;
the ability to continue to hire, train and retain appropriately qualified personnel;
the availability of, and competition for, qualified personnel supporting our natural gas, electricity and propane businesses;
the effect of accounting pronouncements issued periodically by accounting standard-setting bodies; and
the impacts associated with the outbreak of a pandemic, including the duration and scope of the pandemic the
corresponding impact on our supply chains, our personnel, our contract counterparties, general economic conditions and
growth, the financial markets and any costs to comply with governmental mandates.
Chesapeake Utilities Corporation 2019 Form 10-K Page 2
ITEM 1. Business.
Corporate Overview and Strategy
Chesapeake Utilities Corporation is a Delaware corporation formed in 1947 with operations primarily in the Mid-Atlantic
region, North Carolina, South Carolina, Florida and Ohio. We are an energy delivery company engaged in the distribution of
natural gas, electricity and propane; the transmission of natural gas; the generation of electricity and steam, and in providing
related services to our customers. Our strategy is focused on growing earnings from a stable regulated energy delivery
foundation and investing in related businesses and services that provide opportunities for returns greater than traditional utility
returns. We seek to identify and develop opportunities across the energy value chain, with emphasis on midstream and
downstream investments that are accretive to earnings per share, consistent with our long-term growth strategy and create
opportunities to continue our record of top tier returns on equity relative to our peer group. The Company’s growth strategy
includes the continued investment and expansion of the Company’s regulated operations that provide a stable base of earnings,
as well as investments in other related non-regulated businesses and services including sustainable energy initiatives. By
investing in these related business and services, the Company creates opportunities to sustain its track record of higher returns,
as compared to a traditional utility.
Currently, the Company’s growth strategy is focused on the following platforms, including:
• Optimizing the earnings growth in our existing businesses, which includes organic growth, territory expansions, and
new products and services as well as increased opportunities to transform the Company with a focus on people,
process, technology and organizational structure.
Identification and pursuit of additional pipeline expansions, including new interstate and intrastate transmission
projects.
•
• Growth of Marlin Gas Services’ CNG transport business and expansion into LNG and RNG transport services as
•
•
well as methane capture.
Identifying and undertaking additional strategic propane acquisitions that provide a larger foundation in current
markets and expand our brand and presence into new strategic growth markets.
Pursuit of growth opportunities that enable us to utilize our integrated set of energy delivery businesses to
participate in sustainable energy opportunities.
Operating Segments
We operate within two reportable segments: Regulated Energy and Unregulated Energy. The remainder of our operations is
presented as “Other businesses and eliminations." These segments are described below in detail.
Regulated Energy
Overview
Our regulated energy businesses are comprised of natural gas and electric distribution, as well as natural gas transmission
services. The following table presents net income for the year ended December 31, 2021 and total assets as of December 31,
2021, by operation and area served:
Chesapeake Utilities Corporation 2021 Form 10-K Page 3
Operations
(in thousands)
Natural Gas Distribution
Delmarva Natural Gas (1)
Florida Natural Gas (2)
Natural Gas Transmission
Eastern Shore
Peninsula Pipeline
Aspire Energy Express
Electric Distribution
FPU
Total Regulated Energy
Areas Served
Net Income
Total Assets
Delaware/Maryland
Florida
$
12,283 $
16,040
Delaware/Maryland/
Pennsylvania
Florida
Ohio
Florida
21,369
10,898
119
350,196
481,573
482,161
140,494
7,503
$
5,441
66,150 $
167,264
1,629,191
(1) Delmarva Natural Gas consists of Delaware division, Maryland division, Sandpiper Energy and Elkton Gas.
(2) Florida Natural Gas consists of Chesapeake Utilities CFG Division and FPU, and FPU's Ft. Meade and Indiantown divisions.
Revenues in the Regulated Energy segment are based on rates regulated by the PSC in the states in which we operate or, in the
case of Eastern Shore, which is an interstate business, by the FERC. The rates are designed to generate revenues to recover all
prudent operating and financing costs and provide a reasonable return for our stockholders. Each of our distribution and
transmission operations has a rate base, which generally consists of the original cost of the operation's plant, less accumulated
depreciation, working capital and other assets. For Delmarva Natural Gas and Eastern Shore, rate base also includes deferred
income tax liabilities and other additions or deductions. Our Regulated Energy operations in Florida do not include deferred
income tax liabilities in their rate base.
Our natural gas and electric distribution operations bill customers at standard rates approved by their respective state PSC.
Each state PSC allows us to negotiate rates, based on approved methodologies, for large customers that can switch to other
fuels. Some of our customers in Maryland receive propane through underground distribution systems in Worcester County. We
bill these customers under PSC-approved rates and include them in the natural gas distribution results and customer statistics.
Our natural gas and electric distribution operations earn profits on the delivery of natural gas or electricity to customers. The
cost of natural gas or electricity that we deliver is passed through to customers under PSC-approved fuel cost recovery
mechanisms. The mechanisms allow us to adjust our rates on an ongoing basis without filing a rate case to recover changes in
the cost of the natural gas and electricity that we purchase for customers. Therefore, while our distribution operating revenues
fluctuate with the cost of natural gas or electricity we purchase, our distribution adjusted gross margin (which we define as
operating revenues less purchased gas or electricity cost) is generally not impacted by fluctuations in the cost of natural gas or
electricity.
Our natural gas transmission operations bill customers under rate schedules approved by the FERC or at rates negotiated with
customers.
Acquisition of Elkton Gas
In July 2020, we closed on the acquisition of Elkton Gas, which provides natural gas distribution service to approximately
7,000 residential and commercial customers within a franchised area of Cecil County, Maryland. See Item 8, Financial
Statements and Supplementary Data (Note 4, Acquisitions in the consolidated financial statements) for further information.
The results of Elkton Gas are now included within our Delmarva Natural Gas distribution operations.
Operational Highlights
The following table presents operating revenues, volumes and the average number of customers by customer class for our
natural gas and electric distribution operations for the year ended December 31, 2021:
Chesapeake Utilities Corporation 2021 Form 10-K Page 4
Operating Revenues (in thousands)
Residential
Commercial
Industrial
Other (1)
Total Operating Revenues
Volumes (in Dts for natural gas/KW Hours for electric)
Residential
Commercial
Industrial
Other
Total Volumes
Delmarva
Natural Gas
Distribution
Florida
Natural Gas
Distribution (2)
FPU
Electric
Distribution
$
$
73,539
37,507
9,160
1,289
121,495
4,475,634
4,209,015
6,158,412
313,791
15,156,852
61 %
31 %
8 %
<1%
100 %
30 %
28 %
40 %
2 %
100 %
$
$
41,460
34,834
47,418
10,897
134,609
2,024,286
6,270,574
33,945,702
3,418,989
45,659,551
31 %
26 %
35 %
8 %
100 %
5 %
14 %
74 %
7 %
100 %
$
$
37,594
34,591
2,105
4,010
78,300
304,236
305,121
15,361
—
624,718
48 %
44 %
3 %
5 %
100 %
49 %
49 %
2 %
— %
100 %
Average Number of Customers (3)
78 %
87,697
Residential
22 %
7,808
Commercial
<1%
209
Industrial
— %
5
Other
100 %
95,719
Total Average Number of Customers
(1) Operating Revenues from "Other" sources include revenue, unbilled revenue, under (over) recoveries of fuel cost, conservation revenue, other miscellaneous
25,347
7,328
2
—
32,677
81,635
5,684
2,540
6
89,865
92 %
8 %
<1%
<1%
100 %
91 %
6 %
3 %
<1%
100 %
charges, fees for billing services provided to third parties, and adjustments for pass-through taxes.
(2) Florida natural gas distribution includes Chesapeake Utilities' Central Florida Gas division, FPU and FPU's Indiantown and Fort Meade divisions.
(3) Average number of customers is based on the twelve-month average for the year ended December 31, 2021.
The following table presents operating revenues, by customer type, for Eastern Shore and Peninsula Pipeline for the year ended
December 31, 2021, as well as contracted firm transportation capacity by customer type, and design day capacity at
December 31, 2021:
Operating Revenues (in thousands)
Local distribution companies - affiliated (1)
Local distribution companies - non-affiliated
Commercial and industrial - affiliated
Commercial and industrial - non-affiliated
Other (2)
Total Operating Revenues
Contracted firm transportation capacity (in Dts/d)
Local distribution companies - affiliated
Local distribution companies - non-affiliated
Commercial and industrial - affiliated
Commercial and industrial - non-affiliated
Total Contracted firm transportation capacity
Eastern Shore
Peninsula Pipeline
$
$
29,214
24,685
—
22,993
19
76,911
38 % $
32 %
— %
30 %
<1%
100 % $
23,510
840
1,120
264
896
26,630
153,295
56,576
—
98,540
308,411
50 %
18 %
— %
32 %
100 %
306,400
534,825
1,500
5,100
847,825
88 %
3 %
4 %
1 %
4 %
100 %
36 %
63 %
<1%
1 %
100 %
100 %
Design day capacity (in Dts/d)
(1) Eastern Shore's and Peninsula Pipeline's service to our local distribution affiliates is based on the respective regulator's approved rates and is an integral component of the cost
associated with providing natural gas supplies to the end users of those affiliates. We eliminate operating revenues of these entities against the natural gas costs of those affiliates
in our consolidated financial information; however, our local distribution affiliates include this amount in their purchased fuel cost and recover it through fuel cost recovery
mechanisms.
100 %
308,411
847,825
(2) Operating revenues from "Other" sources are from the rental of gas properties.
Chesapeake Utilities Corporation 2021 Form 10-K Page 5
Regulatory Overview
The following table highlights key regulatory information for each of our principal Regulated Energy operations. Peninsula
Pipeline and Aspire Energy Express are not regulated with regard to cost of service by either the Florida PSC or Ohio PUC
respectively, or FERC and is therefore excluded from the table. See Item 8, Financial Statements and Supplementary Data
(Note 19, Rates and Other Regulatory Activities, in the consolidated financial statements) for further discussion on the impact
of this legislation on our regulated businesses.
Natural Gas Distribution
Delmarva
Florida
Electric
Distribution
Natural Gas
Transmission
Operation/Division Delaware Maryland
Sandpiper Elkton Gas (7)
Chesapeake's
Florida natural
gas division
FPU
FPU
Eastern Shore
Regulatory Agency
Effective date - Last
Rate Order
Rate Base (in Rates)
(in Millions)
Annual Rate Increase
Approved (in Millions)
Capital Structure (in
rates)(3)*
Allowed Return on
Equity
TJCA Refund Status
associated with
customer rates
Delaware
PSC
Maryland PSC
Florida PSC
FERC
01/01/2017
12/1/2007
12/01/2019
02/07/2019
01/14/2010
01/14/2010(1)
10/8/2020
08/01/2017
Not stated
Not stated
Not stated
Not stated
$46.7
$68.9
$24.9
Not stated
$2.3
$0.6
N/A(2)
$0.1
$2.5
$8.0
$3.4 base rate and
$7.7 from storm
surcharge
$9.8
LTD: 42%
STD: 5%
Equity: 53%
Not stated
Not stated
LTD: 50%
Equity: 50%
LTD: 31% STD:
6% Equity: 43%
Other: 20%
LTD: 31% Equity:
47% Other:
22%
LTD: 22% STD:
23% Equity: 55%
Not stated
9.75% (4)
10.75%(4)
Not stated (5)
9.80%
10.80%(4)
10.85%(4)
10.25%(4), (6)
Not stated
Refunded
Refunded
Refunded
N/A
Retained
Retained
Refunded
Refunded
(1) The effective date of the order approving the settlement agreement, which adjusted the rates originally approved on June 4, 2009.
(2) The Maryland PSC approved a declining return on equity that will result in a decline in our rates.
(3) Other components of capital structure include customer deposits, deferred income taxes and tax credits.
(4) Allowed after-tax return on equity.
(5) The terms of the agreement include revenue neutral rates for the first year (December 1, 2016 through November 30, 2017), followed by a schedule of
rate reductions in subsequent years based upon the projected rate of propane to natural gas conversions.
(6) The terms of the settlement agreement for the FPU electric division limited proceeding with the Florida PSC prescribed an authorized return on equity
range of 9.25 to 11.25 percent, with a mid-point of 10.25 percent.
(7) The rate increase and allowed return on equity for Elkton Gas were approved by the Maryland PSC before we acquired the company.
* LTD-Long-term debt; STD-Short-term debt.
In October 2018, Hurricane Michael passed through FPU's electric distribution operation's service territory in Northwest
Florida and caused widespread and severe damage to FPU's infrastructure resulting in the loss of electric service to 100 percent
of its customers in the Northwest Florida service territory. FPU expended more than $65.0 million to restore service, which
was recorded as new plant and equipment, charged against FPU’s accumulated depreciation or charged against FPU’s storm
reserve.
In late 2019, the Florida PSC approved an interim rate increase, subject to refund, effective January 1, 2020, associated with
the restoration effort following Hurricane Michael. We fully reserved these interim rates, pending a final resolution and
settlement of the limited proceeding. In September 2020, the Florida PSC approved a settlement agreement between FPU and
the Office of the Public Counsel regarding final cost recovery and rates associated with Hurricane Michael. The settlement
agreement allowed us to: (a) refund the over-collection of interim rates through the fuel clause; (b) record regulatory assets for
storm costs in the amount of $45.8 million including interest which will be amortized over six years; (c) recover these storm
costs through a surcharge totaling $7.7 million annually; and (d) collect an annual increase in revenue of $3.3 million to recover
capital costs associated with new plant investments and a regulatory asset for the cost of removal and unrecovered plant costs.
The new base rates and storm surcharge were effective on November 1, 2020.
Chesapeake Utilities Corporation 2021 Form 10-K Page 6
In September 2019, FPU filed a petition, with the Florida PSC, for approval of its consolidated electric depreciation rates. The
petition was joined to the Hurricane Michael docket, and was approved at the Florida PSC Agenda in September 2020. The
approved rates were retroactively applied effective January 1, 2020. See Item 8, Financial Statements and Supplementary Data
(Note 19, Rates and Other Regulatory Activities, in the consolidated financial statements) for further information.
The following table presents surcharge and other mechanisms that have been approved by the respective PSC for our regulated
energy distribution businesses. These include Delaware surcharges to expand natural gas service in its service territory as well
as for the conversion of propane distribution systems to natural gas, Maryland’s surcharges to fund natural gas conversions and
system improvements in Worcester County, Florida’s GRIP surcharge which provides accelerated recovery of the costs of
replacing older portions of the natural gas distribution system to improve safety and reliability and the Florida electric
distribution operation's limited proceeding which allowed recovery of storm-related costs.
Operation(s)/Division(s)
Delaware division
Maryland division
Sandpiper Energy
Elkton Gas
FPU and Central Florida Gas natural gas divisions
FPU electric division
Weather
Jurisdiction
Delaware
Maryland
Maryland
Maryland
Florida
Florida
Infrastructure
mechanism
Yes
No
Yes
Yes
Yes
Yes
Revenue
normalization
No
Yes
Yes
Yes
No
No
Weather variations directly influence the volume of natural gas and electricity sold and delivered to residential and commercial
customers for heating and cooling and changes in volumes delivered impact the revenue generated from these customers.
Natural gas volumes are highest during the winter months, when residential and commercial customers use more natural gas
for heating. Demand for electricity is highest during the summer months, when more electricity is used for cooling. We measure
the relative impact of weather using degree-days. A degree-day is the measure of the variation in the weather based on the
extent to which the average daily temperature falls above or below 65 degrees Fahrenheit. Each degree of temperature below
65 degrees Fahrenheit is counted as one heating degree-day, and each degree of temperature above 65 degrees Fahrenheit is
counted as one cooling degree-day. Normal heating and cooling degree-days are based on the most recent 10-year average.
Competition
Natural Gas Distribution
While our natural gas distribution operations do not compete directly with other distributors of natural gas for residential and
commercial customers in our service areas, we do compete with other natural gas suppliers and alternative fuel providers for
sales to industrial customers. Large customers could bypass our natural gas distribution systems and connect directly to
intrastate or interstate transmission pipelines, and we compete in all aspects of our natural gas business with alternative energy
sources, including electricity, oil, propane and renewables. The most effective means to compete against alternative fuels are
lower prices, superior reliability and flexibility of service. Natural gas historically has maintained a price advantage in the
residential, commercial and industrial markets, and reliability of natural gas supply and service has been excellent. In addition,
we provide flexible pricing to our large customers to minimize fuel switching and protect these volumes and their contributions
to the profitability of our natural gas distribution operations.
Natural Gas Transmission
Our natural gas transmission business competes with other interstate and intrastate pipeline companies to provide service to
large industrial, generation and distribution customers, primarily in the northern portion of the Delmarva Peninsula and in
Florida. Our transmission business in Ohio, Aspire Energy Express, services one client, Guernsey Power Station, to which it is
the sole supplier.
Chesapeake Utilities Corporation 2021 Form 10-K Page 7
Electric Distribution
While our electric distribution operations do not compete directly with other distributors of electricity for residential and
commercial customers in our service areas, we do compete with other electricity suppliers and alternative fuel providers for
sales to industrial customers. Some of our large industrial customers may be capable of generating their own electricity, and
we structure rates, service offerings and flexibility to retain these customers in order to retain their business and contributions
to the profitability of our electric distribution operations.
Supplies, Transmission and Storage
Natural Gas Distribution
Our natural gas distribution operations purchase natural gas from marketers and producers and maintain contracts for
transportation and storage with several interstate pipeline companies to meet projected customer demand requirements. We
believe that our supply and capacity strategy will adequately meet our customers’ needs over the next several years and we will
continue to adapt our supply strategy to meet projected growth in customer demand within our service territories.
The Delmarva natural gas distribution systems are directly connected to Eastern Shore’s pipeline, which has connections to
other pipelines that provide us with transportation and storage. These operations can also use propane-air and liquefied natural
gas peak-shaving equipment to serve customers. In March 2020, our Delmarva Peninsula natural gas distribution operations
entered into asset management agreements with a third party to manage their natural gas transportation and storage capacity.
The agreements were effective as of April 1, 2020 and expire on March 31, 2023. Our Delmarva operations receive a fee, which
we share with our customers, from the asset manager, who optimizes the transportation, storage and natural gas supply for these
operations.
Our Florida natural gas distribution operation uses Peninsula Pipeline and Peoples Gas to transport natural gas where there is
no direct connection with FGT. In November 2020, FPU natural gas distribution and Eight Flags entered into separate 10-year
asset management agreements with Emera Energy Services, Inc. to manage their natural gas transportation capacity. An
agreement with Florida Southeast Connection LLC commenced in June 2020 for additional service to Palm Beach County for
an initial term through December 2044.
A summary of our pipeline capacity contracts follows:
Division
Delmarva Natural Gas Distribution
Pipeline
Eastern Shore
Columbia Gas(1)
Transco(1)
TETLP(1)
Maximum Daily Firm
Transportation Capacity
(Dts)
151,026
5,246
30,419
50,000
Contract
Expiration Date
2022-2035
2023-2024
2022-2028
2027
Florida Natural Gas Distribution
Gulfstream(2)
FGT
Peninsula Pipeline
Peoples Gas
Florida Southeast Connection
LLC
Southern Natural Gas Company
10,000
45,909 - 77,317
306,400
12,660
5,000
1,750
2022
2023-2041
2033-2048
2022-2024
2044
2030
(1) Transco, Columbia Gas and TETLP are interstate pipelines interconnected with Eastern Shore's pipeline
(2) Pursuant to a capacity release program approved by the Florida PSC, all of the capacity under this agreement has been released to various third parties.
Under the terms of these capacity release agreements, Chesapeake Utilities is contingently liable to Gulfstream should any party, that acquired the capacity
through release, fail to pay the capacity charge.
Eastern Shore has three agreements with Transco for a total of 7,292 Dts/d of firm daily storage injection and withdrawal
Chesapeake Utilities Corporation 2021 Form 10-K Page 8
entitlements and total storage capacity of 288,003 Dts. These agreements expire in March 2023. Eastern Shore retains these
firm storage services in order to provide swing transportation service and firm storage service to customers requesting such
services.
Aspire Energy Express, our Ohio intrastate pipeline subsidiary, entered into a precedent agreement for firm transportation
capacity with Guernsey Power Station, who is currently constructing a power generation facility. Aspire Energy Express will
provide firm natural gas transportation service to this facility. Guernsey Power Station commenced construction of the project
in October 2019. Aspire Energy Express completed construction of the gas transmission facilities to the power generation
facility in the fourth quarter of 2021 and expects to begin billing for transportation services in the first quarter of 2022.
Electric Distribution
Our Florida electric distribution operation purchases wholesale electricity under the power supply contracts summarized below:
Area Served by Contract
Northwest Florida
Northeast Florida
Northeast Florida
Northeast Florida
Northeast Florida
Counterparty
Gulf Power Company
Florida Power & Light Company
Eight Flags
Rayonier
WestRock Company
Contracted Amount (MW) Contract Expiration Date
Full Requirement*
Full Requirement*
21
1.7 to 3.0
As-available
2026
2026
2036
2036
N/A
*The counter party is obligated to provide us with the electricity to meet our customers’ demand, which may vary.
Unregulated Energy
Overview
The following table presents net income for the year ended December 31, 2021 and total assets as of December 31, 2021, for
our Unregulated Energy segment by operation and area served:
Operations
(in thousands)
Propane Operations (Sharp,
Diversified Energy, FPU and
Flo-gas) (1)
Energy Transmission (Aspire
Energy)
Energy Generation (Eight Flags)
Marlin Gas Services
Total
Area Served
Net Income
Total Assets
Delaware, Maryland, Virginia,
Pennsylvania, North Carolina, South
Carolina, Florida
Ohio
Florida
The Eastern U.S.
$
$
11,651 $
3,060
1,900
370
16,981 $
197,340
141,473
38,060
61,567
438,440
Chesapeake Utilities Corporation 2021 Form 10-K Page 9
(1) Includes results and total assets for Western Natural Gas, which we acquired in October 2020. See Item 8, Financial Statements and Supplementary Data
(Note 4, Acquisitions in the consolidated financial statements) for further information.
Propane Operations
Our propane operations sell propane to residential, commercial/industrial, wholesale and AutoGas customers, in the Mid-
Atlantic region, North Carolina, South Carolina and Florida, through Sharp Energy, Inc., Sharpgas, Inc., Diversified Energy,
FPU and Flo-gas. We deliver to and bill our propane customers based on two primary customer types: bulk delivery customers
and metered customers. Bulk delivery customers receive deliveries into tanks at their location. We invoice and record revenues
for these customers at the time of delivery. Metered customers are either part of an underground propane distribution system
or have a meter installed on the tank at their location. We invoice and recognize revenue for these customers based on their
consumption as dictated by scheduled meter reads. As a member of AutoGas Alliance, we install and support propane vehicle
conversion systems for vehicle fleets and provide on-site fueling infrastructure.
Propane Operations - Operational Highlights
For the year ended December 31, 2021, operating revenues, volumes sold and average number of customers by customer class
for our propane operations were as follows:
Operating Revenues
(in thousands)(2)
Volumes
(in thousands of gallons)(2)
Average Number of
Customers (1)(2)
Residential bulk
Residential metered
Commercial bulk
Commercial metered
Wholesale
AutoGas
Other (3)
Total
$
$
40,002
17,095
31,695
1,764
30,965
5,678
14,883
142,082
28 %
12 %
22 %
1 %
22 %
4 %
11 %
100 %
14,326
5,894
17,124
641
26,762
3,652
21 %
9 %
25 %
1 %
39 %
5 %
— — %
100 %
68,399
44,866
17,486
6,327
234
48
92
—
69,053
65 %
25 %
10 %
<1%
<1%
<1%
— %
100 %
(1) Average number of customers is based on a twelve-month average for the year ended December 31, 2021.
(2) Operating revenues, volumes and average customer includes those for Diversified Energy that was acquired in December 2021. See Item 8, Financial
Statements and Supplementary Data (Note 4, Acquisitions in the consolidated financial statements) for further information.
(3) Operating revenues from "Other" sources include revenues from customer loyalty programs; delivery, service and appliance fees; and unbilled revenues.
Competition
Our propane operations compete with national and local independent companies primarily on the basis of price and service.
Propane is generally a cheaper fuel for home heating than oil and electricity but more expensive than natural gas. Our propane
operations are largely concentrated in areas that are not currently served by natural gas distribution systems.
Supplies, Transportation and Storage
We purchase propane from major oil companies and independent natural gas liquids producers. Propane is transported by truck
and rail to our bulk storage facilities in Pennsylvania, Delaware, Maryland, Virginia, North Carolina, South Carolina and Florida
which have a total storage capacity of 8.9 million gallons. Deliveries are made from these facilities by truck to tanks located
on customers’ premises or to central storage tanks that feed our underground propane distribution systems. While propane
supply has traditionally been adequate, significant fluctuations in weather, closing of refineries and disruption in supply chains,
could cause temporary reductions in available supplies.
Weather
Propane revenues are affected by seasonal variations in temperature and weather conditions, which directly influence the
volume of propane used by our customers. Our propane revenues are typically highest during the winter months when propane
is used for heating. Sustained warmer-than-normal temperatures will tend to reduce propane use, while sustained colder-than-
normal temperatures will tend to increase consumption.
Chesapeake Utilities Corporation 2021 Form 10-K Page 10
Unregulated Energy Transmission and Supply (Aspire Energy)
Aspire Energy owns approximately 2,800 miles of natural gas pipeline systems in 40 counties in Ohio. The majority of Aspire
Energy’s revenues are derived from long-term supply agreements with Columbia Gas of Ohio and Consumers Gas Cooperative
("CGC"), which together serve more than 22,000 end-use customers. Aspire Energy purchases natural gas to serve these
customers from conventional producers in the Marcellus and Utica natural gas production areas. In October 2021, Aspire
Energy completed construction of its Noble Road Landfill RNG pipeline project, which began transporting RNG generated
from the landfill to Aspire Energy’s pipeline system in January of 2022, displacing conventionally produced natural gas. The
RNG volume is estimated to represent nearly 10 percent of Aspire Energy’s gas gathering volumes in the future. In addition,
Aspire Energy earns revenue by gathering and processing natural gas for customers.
For the twelve-month period ended December 31, 2021, Aspire Energy's operating revenues and deliveries by customer type
were as follows:
Operating revenues
Deliveries
Supply to Columbia Gas of Ohio
Supply to CGC
Supply to Marketers - unaffiliated
Other (including natural gas gathering and processing)
Total
Energy Generation (Eight Flags)
(in thousands) % of Total (in thousands Dts) % of Total
44 %
$
29 %
26 %
1 %
100 %
39 %
42 %
13 %
6 %
100 %
15,062
16,111
4,778
2,212
38,163
2,556
1,675
1,507
71
5,809
$
Eight Flags generates electricity and steam at its CHP plant located on Amelia Island, Florida. The plant is powered by natural
gas transported by Peninsula Pipeline and our Florida natural gas distribution operation and produces approximately 21 MW
of electricity and 75,000 pounds per hour of steam. Eight Flags sells the electricity generated from the plant to our Florida
electric distribution operation and sells the steam to the customer who owns the site on which the plant is located both under
separate 20-year contracts.
Marlin Gas Services
Marlin Gas Services is a supplier of mobile CNG and virtual pipeline solutions, primarily to utilities and pipelines. Marlin Gas
Services provides temporary hold services, pipeline integrity services, emergency services for damaged pipelines and
specialized gas services for customers who have unique requirements. These services are provided by a highly trained staff of
drivers and maintenance technicians who safely perform these functions throughout the eastern United States. Marlin Gas
Services maintains a fleet of CNG trailers, mobile compression equipment, LNG tankers and vaporizers, and an internally
developed patented regulator system which allows for delivery of over 7,000 Dts/d of natural gas. Marlin Gas Services
continues to actively expand the territories it serves, as well as leveraging its fleet of equipment and patented technologies to
serve liquefied natural gas and RNG market needs.
Environmental Matters
See Item 8, Financial Statements and Supplementary Data (see Note 20, Environmental Commitments and Contingencies, in
the consolidated financial statements).
Human Capital Initiatives
Our success is the direct result of our employees and our strong culture that fully engages our team and promotes equity,
diversity, inclusion, integrity, accountability and reliability. We believe that a combination of diverse team members and an
inclusive culture contributes to the success of our Company and to enhanced societal advancement. Each employee is a valued
member of our team bringing a diverse perspective to help grow our business and achieve our goals. Our tradition of serving
employees, customers, investors, partners and communities is at the core of our culture. Among the ongoing initiatives across
Chesapeake Utilities Corporation 2021 Form 10-K Page 11
our enterprise, we highlight below the importance of our team, as well as our response to the COVID-19 pandemic, our culture
of safety, and our environmental, social and governance stewardship.
Our Team Drives Our Performance
Our employees are the key to our success. Our leadership and human resources teams are responsible for attracting and retaining
top talent. In 2021, the Company hired a new Chief Human Resources Officer, with expertise in diverse candidate recruitment,
to ensure that we continue to expand our candidate pools to better reflect the diverse demographics of the communities we
serve.
Throughout our organization, we seek to promote from within, reviewing strategic positions regularly and identifying potential
internal candidates to fill those positions, evaluating critical job skill sets to identify competency gaps and creating
developmental plans to facilitate employee professional growth. We provide training and development programs as well as
tuition reimbursement to promote continued professional growth.
As of December 31, 2021, we had a total of 1,007 employees, 110 of whom are union employees represented by two labor
unions: the International Brotherhood of Electrical Workers and the United Food and Commercial Workers Union. The
collective bargaining agreements with these labor unions expire in 2022. We consider our relationships with employees,
including those covered by collective bargaining agreements, to be in good standing. We provide a competitive Total Rewards
package for our employees including health insurance coverage, wellness initiatives, retirement savings benefits, paid time off,
employee assistance programs, educational and tuition reimbursement, competitive pay, career growth opportunities, paid
volunteer time, and a culture of recognition. In 2021, the Company was recognized as a Top Workplace for the tenth consecutive
year. These honors were based entirely on feedback from employees who were surveyed by the research firm ‘Energage’. In
early 2022, the Company was recognized nationally as a 2022 Top Workplace USA recipient among mid-sized companies for
the second consecutive year. These recognitions are a testament to our employees’ commitment to excellence. Our employees
are the backbone of our continued growth and success.
In 2020, we enhanced our diversity initiatives and established an Equity, Diversity and Inclusion (“EDI”) Council. The Council
recommends and promotes our EDI strategy, advises employee resource groups (“ERGs”) and works with our operating units
and support teams on EDI initiatives. The EDI Council’s charter includes the following objectives:
• Build a more diverse and inclusive workforce
• Promote a culture of understanding, equality and inclusion
• Educate employees about the benefits of diversity at Chesapeake Utilities
• Support community programs and organizations that are diverse and inclusive
• Provide guidance on EDI matters for the Company
The Chesapeake Utilities EDI Council includes members of our leadership team, the chairs of each of our ERGs and other
individuals in key support roles. The CEO receives a regular report on the achievements of the EDI Council, strategic direction
of initiatives, resource needs and issues that require policy decisions or other actions.
In 2021, there were six active ERGs meeting throughout the Company. Early in 2022, two new ERGs were added. ERGs are
voluntary, employee-led groups that focus on shared identities, affinities and experiences and seek to apply those perspectives
to initiatives that create value throughout the Company. The ERGs support the members' personal growth and professional
development, and help develop learning programs and community service opportunities throughout the Company. ERGs also
help foster a sense of belonging by creating a deep and intentional community that extends beyond an employee’s day-to-day
team and colleagues into a companywide network.
COVID-19 Response
In March 2020, the United States declared a national emergency in response to the COVID-19 pandemic. In response to this
declaration and the rapid spread of COVID-19 within the United States, federal, state and local governments throughout the
Chesapeake Utilities Corporation 2021 Form 10-K Page 12
country imposed varying degrees of restrictions on social and commercial activity to promote social distancing in an effort to
slow the spread of the illness. These restrictions significantly impacted economic conditions in the United States in 2020 and
continued into 2021. Chesapeake Utilities is considered an “essential business,” which has allowed us to continue operational
activities and construction projects while adhering to the social distancing restrictions that were in place.
Throughout 2021, restrictions continued to be lifted as vaccines have become widely available in the United States. For
example, the state of emergency in Florida was terminated in May 2021 followed by Delaware and Maryland in July 2021,
resulting in reduced restrictions. The expiration of the states of emergency in our service territories, along with the settlement
of our limited proceeding in Florida, has concluded our ability to defer incremental pandemic related costs for consideration
through the applicable regulatory process.
We have been closely following the legal process related to the Occupational Safety and Health Administration (OSHA)
Emergency Temporary Standard (ETS) mandating that all employers, with 100 or more employees, require COVID-19
vaccinations or weekly testing, which made its way to the United States Supreme Court. While OSHA has withdrawn the ETS
as a temporary standard following the Supreme Court’s ruling, we will continue to monitor its status as a proposed rule. In
light of the continued emergence and growing prevalence of the new variants of COVID-19, such as the Omicron variant, we
continue to operate under our pandemic response plan, monitor developments affecting employees, customers, suppliers, and
stockholders and take all precautions warranted to operate safely and to comply with the CDC and OSHA standards, in order
to protect our employees, customers and the communities we serve. We continue to hold regular companywide all employee
calls and leadership meetings with our President and CEO to discuss, among other things, matters pertaining to COVID-19, in
addition to distributing frequent, routine communications updates. The Company’s Board met regularly and virtually,
throughout 2021, and received updates on the Company’s actions related to COVID-19, the Company’s safety protocols, and
ongoing monitoring, including updates on the Company’s COVID-19 Human Resources Taskforce’s priorities and current
employee health statistics, and the Company’s risk posture.
Workplace Safety
We believe that there is nothing more important than the safety of our team, our customers and our communities. We are
committed to ensuring safety is at the center of our culture and the way we do business. The importance of safety is exhibited
throughout the entire organization, with the direction and tone set by both our Board and our President and CEO, and including
required attendance at monthly safety meetings, routine safety training and the inclusion of safety moments at key team
meetings.
To maintain safety as a priority, our employees remain committed and work together to ensure that our plans, programs, policies
and behaviors are aligned with our aspirations as a Company. The achievement of superior safety performance is both an
important short-term and long-term strategic initiative in managing our operations. In November 2020, we announced the
completion of our state-of-the art training facility in Dover, Delaware. ‘Safety Town’ now serves as a resource for training our
employees who build, maintain and operate our natural gas infrastructure, offering hands-on training and fully immersive, on-
the-job field experiences. First responders and other community partners also benefit from the simulated environment and
conditions they could encounter as they enter homes in the community. We are excited to start construction of a second ‘Safety
Town’ facility in Florida in 2022.
Environmental, Social and Governance Stewardship ("ESG")
Consistent with our culture of teamwork, the broad responsibility of ESG stewardship is supported across our organization by
the dedication and efforts of our Board of Directors and its Committees, as well as the entrepreneurship and dedication of our
team. As stewards of long-term enterprise value, the Board of Directors is committed to overseeing the sustainability of the
Company and its safety and operational compliance practices, and to promoting equity, diversity and inclusion that reflects the
diverse communities we serve. The Corporate Governance Committee oversees our ESG activities and initiatives to continue
enhancing our culture of sustainability and corporate governance practices. The Audit Committee oversees the integrity of our
financial statements and financial reporting process, our risk exposure, and implementation and effectiveness of our risk
management programs. The Compensation Committee promotes a culture of equity, diversity and inclusion and contributes to
the ability to attract, retain, develop and motivate both at the executive level and throughout the organization. Finally, the
Chesapeake Utilities Corporation 2021 Form 10-K Page 13
Investment Committee assists the Board of Directors with evaluating investments pursuant to or in support of our growth
strategy, both organically and through acquisitions, including renewable natural gas and other sustainable initiatives.
Information About Executive Officers
Set forth below are the names, ages, and positions of our executive officers with their recent business experience. The age of
each officer is as of the filing date of this Annual Report.
Name
Jeffry M. Householder
Age
64
2010
Executive
Officer Since Offices Held During the Past Five Years
Beth W. Cooper
55
2005
James F. Moriarty
64
2015
Kevin J. Webber
63
2010
President (January 2019 - present)
Chief Executive Officer (January 2019 - present)
Director (January 2019 - present)
President of FPU (June 2010 - February 2019)
Executive Vice President (February 2019 - present)
Chief Financial Officer (September 2008 - present)
Senior Vice President (September 2008 - February 2019)
Assistant Corporate Secretary (March 2015 - present)
Executive Vice President (February 2019 - present)
General Counsel & Corporate Secretary (March 2015 - present)
Chief Policy and Risk Officer (February 2019 - present)
Senior Vice President (February 2017 - February 2019)
Vice President (March 2015 - February 2017)
Chief Development Officer (January 2022 - present)
Senior Vice President (February 2019 - present)
President FPU (February 2019 - December 2019)
Vice President Gas Operations and Business Development Florida
Business Units (July 2010 - February 2019)
Jeffrey S. Sylvester
52
2019
Chief Operating Officer (January 2022 - present)
Senior Vice President (December 2019 - present)
Vice President Black Hills Energy (October 2012 - December 2019)
Available Information on Corporate Governance Documents
Our Annual Reports on Form 10-K, Quarterly Reports on Form 10-Q, Current Reports on Form 8-K and other reports and
amendments to these reports that we file with or furnish to the SEC at their website, www.sec.gov, are also available free of
charge at our website, www.chpk.com, as soon as reasonably practicable after we electronically file these reports with, or furnish
these reports to the SEC. The content of this website is not part of this Annual Report.
In addition, the following documents are available free of charge on our website, www.chpk.com:
• Business Code of Ethics and Conduct applicable to all employees, officers and directors;
• Code of Ethics for Financial Officers;
• Corporate Governance Guidelines; and
• Charters for the Audit Committee, Compensation Committee, Investment Committee, and Corporate Governance
Committee of the Board of Directors.
Any of these reports or documents may also be obtained by writing to: Corporate Secretary; c/o Chesapeake Utilities
Corporation, 500 Energy Lane Suite 100, Dover, DE 19904.
Chesapeake Utilities Corporation 2021 Form 10-K Page 14
ITEM 1A. RISK FACTORS.
The following is a discussion of the primary factors that may affect the operations and/or financial performance of our regulated
and unregulated energy businesses. Refer to the section entitled Item 7, Management’s Discussion and Analysis of Financial
Condition and Results of Operations of this Annual Report for an additional discussion of these and other related factors that
affect our operations and/or financial performance.
FINANCIAL RISKS
Instability and volatility in the financial markets could negatively impact access to capital at competitive rates, which could
affect our ability to implement our strategic plan, undertake improvements and make other investments required for our
future growth.
Our business strategy includes the continued pursuit of growth and requires capital investment in excess of cash flow from
operations. As a result, the successful execution of our strategy is dependent upon access to equity and debt at reasonable costs.
Our ability to issue new debt and equity capital and the cost of equity and debt are greatly affected by our financial performance
and the conditions of the financial markets. In addition, our ability to obtain adequate and cost-effective debt depends on our
credit ratings. A downgrade in our current credit ratings could negatively impact our access to and cost of debt. If we are not
able to access capital at competitive rates, our ability to implement our strategic plan, undertake improvements and make other
investments required for our future growth may be limited.
Fluctuations in propane gas prices could negatively affect results of operations.
We adjust the price of the propane we sell based on changes in our cost of purchasing propane. However, if the market does
not allow us to increase propane sales prices to compensate fully for fluctuations in purchased propane costs, our results of
operations and cash flows could be negatively affected.
If we fail to comply with our debt covenant obligations, we could experience adverse financial consequences that could
affect our liquidity and ability to borrow funds.
Our long-term debt obligations and the Revolver contain financial covenants related to debt-to-capital ratios and interest-
coverage ratios. Failure to comply with any of these covenants could result in an event of default which, if not cured or waived,
could result in the acceleration of outstanding debt obligations or the inability to borrow under certain credit agreements. Any
such acceleration could cause a material adverse change in our financial condition. As of December 31, 2021, we were in
compliance with all of our covenants.
Increases in interest rates may adversely affect our results of operations and cash flows.
Increases in interest rates could increase the cost of future debt issuances. Absent recovery of the higher debt cost in the rates
we charge our utility customers, our earnings could be adversely affected. Increases in short-term interest rates could negatively
affect our results of operations, which depend on short-term debt to finance accounts receivable and storage gas inventories
and to temporarily finance capital expenditures. Reference should be made to Item 7A, Quantitative and Qualitative Disclosures
about Market Risk for additional information.
Current market conditions could adversely impact the return on plan assets for FPU's pension plan, which may require
significant additional funding.
In 2021, the Company terminated the Chesapeake Utilities pension plan. The FPU pension plan is closed to new employees,
and the future benefits are frozen. The costs of providing benefits and related funding requirements of the FPU plan is subject
to changes in the market value of the assets that fund the plan and the discount rates used to estimate the pension benefit
obligations. The funded status of the plans and the related costs reflected in our financial statements are affected by various
factors that are subject to an inherent degree of uncertainty, particularly in the current economic environment. Future losses of
asset values and further declines in discount rates may necessitate accelerated funding of the plans to meet minimum federal
Chesapeake Utilities Corporation 2021 Form 10-K Page 15
government requirements and may result in higher pension expense in future years. Adverse changes in the benefit obligations
of the FPU pension plan may require us to record higher pension expense and fund obligations earlier than originally planned,
which would have an adverse impact on our cash flows from operations, decrease borrowing capacity and increase interest
expense.
OPERATIONAL RISKS
We are dependent upon construction of new facilities to support future growth in earnings in our natural gas and electric
distribution and natural gas transmission operations.
Construction of new facilities required to support future growth is subject to various regulatory and developmental risks,
including but not limited to: (i) our ability to obtain timely certificate authorizations, necessary approvals and permits from
regulatory agencies and on terms that are acceptable to us; (ii) potential changes in federal, state and local statutes and
regulations, including environmental requirements, that prevent a project from proceeding or increase the anticipated cost of
the project; (iii) our inability to acquire rights-of-way or land rights on a timely basis on terms that are acceptable to us; (iv) lack
of anticipated future growth in available natural gas and electricity supply; (v) insufficient customer throughput commitments;
and (vi) lack of available and qualified third-party contractors which could impact the timely construction of new facilities.
We operate in a competitive environment, and we may lose customers to competitors.
Natural Gas. Our natural gas transmission and distribution operations compete with interstate pipelines when our customers
are located close enough to a competing pipeline to make direct connections economically feasible. Customers also have the
option to switch to alternative fuels, including renewable energy sources. Failure to retain and grow our natural gas customer
base would have an adverse effect on our financial condition, cash flows and results of operations.
Electric. Our Florida electric distribution business has remained substantially free from direct competition from other electric
service providers but does face competition from other energy sources. Changes in the competitive environment caused by
legislation, regulation, market conditions, or initiatives of other electric power providers, particularly with respect to retail
electric competition, could adversely affect our results of operations, cash flows and financial condition.
Propane. Our propane operations compete with other propane distributors, primarily on the basis of service and price. Our
ability to grow the propane operations business is contingent upon capturing additional market share, expanding into new
markets, and successfully utilizing pricing programs that retain and grow our customer base. Failure to retain and grow our
customer base in our propane operations would have an adverse effect on our results of operations, cash flows and financial
condition.
Fluctuations in weather may cause a significant variance in our earnings.
Our natural gas distribution, propane operations and natural gas transmission operations, are sensitive to fluctuations in weather
conditions, which directly influence the volume of natural gas and propane we transport, sell and deliver to our customers. A
significant portion of our natural gas distribution, propane operations and natural gas transmission revenue is derived from the
sales and deliveries to residential, commercial and industrial heating customers during the five-month peak heating season
(November through March). Other than our Maryland natural gas distribution businesses (Maryland division, Sandpiper Energy
and Elkton Gas) which have revenue normalization mechanisms, if the weather is warmer than normal, we sell and deliver less
natural gas and propane to customers, and earn less revenue, which could adversely affect our results of operations, cash flows
and financial condition. Likewise, if the weather is colder than normal, we sell and deliver more natural gas and propane to
customers, and earn more revenue, which could positively affect our results of operations, cash flows and financial condition.
Variations in weather from year to year can cause our results of operations, cash flows and financial condition to vary
accordingly.
Our electric distribution operation is also affected by variations in weather conditions and unusually severe weather conditions.
However, electricity consumption is generally less seasonal than natural gas and propane because it is used for both heating
and cooling in our service areas.
Chesapeake Utilities Corporation 2021 Form 10-K Page 16
Natural disasters, severe weather (such as a major hurricane) and acts of terrorism could adversely impact earnings.
Inherent in energy transmission and distribution activities are a variety of hazards and operational risks, such as leaks, ruptures,
fires, explosions, sabotage and mechanical problems. Natural disasters and severe weather may damage our assets, cause
operational interruptions and result in the loss of human life, all of which could negatively affect our earnings, financial
condition and results of operations. Acts of terrorism and the impact of retaliatory military and other action by the United States
and its allies may lead to increased political, economic and financial market instability and volatility in the price of natural gas,
electricity and propane that could negatively affect our operations. Companies in the energy industry may face a heightened
risk of exposure to acts of terrorism, which could affect our results of operations, cash flows and financial condition. The
insurance industry may also be affected by natural disasters, severe weather and acts of terrorism; as a result, the availability
of insurance covering risks against which we and our competitors typically insure may be limited. In addition, the insurance
we are able to obtain may have higher deductibles, higher premiums and more restrictive policy terms, which could adversely
affect our results of operations, financial condition and cash flows.
Operating events affecting public safety and the reliability of our natural gas and electric distribution and transmission
systems could adversely affect our operations and increase our costs.
Our natural gas and electric operations are exposed to operational events and risks, such as major leaks, outages, mechanical
failures and breakdown, operations below the expected level of performance or efficiency, and accidents that could affect public
safety and the reliability of our distribution and transmission systems, significantly increase costs and cause loss of customer
confidence. If we are unable to recover all or some of these costs from insurance and/or customers through the regulatory
process, our results of operations, financial condition and cash flows could be adversely affected.
A security breach disrupting our operating systems and facilities or exposing confidential information may adversely affect
our reputation, disrupt our operations and increase our costs.
The cybersecurity risks associated with the protection of our infrastructure and facilities is evolving and increasingly complex.
We continue to heavily rely on technological tools that support our business operations and corporate functions while enhancing
our security. There are various risks associated with our information technology infrastructure, including hardware and software
failure, communications failure, data distortion or destruction, unauthorized access to data, misuse of proprietary or confidential
data, unauthorized control through electronic means, cyber-attacks, cyber-terrorism, data breaches, programming mistakes, and
other inadvertent errors or deliberate human acts. Further, the U.S. government has issued public warnings that indicate energy
assets might be specific targets of cybersecurity threats by foreign sources.
The failure of, or security breaches related to, our information technology infrastructure, could lead to system disruptions or
cause facility shutdowns. Any such failure, attack, or security breach could adversely impact our ability to safely and reliably
deliver services to our customers through our transmission, distribution, and generation systems, subject to us to reputational
and other harm, and subject us to legal and regulatory proceedings and claims and demands from third parties, any of which
could adversely affect our business, our earnings, results of operation and financial condition. In addition, the protection of
customer, employee and Company data is crucial to our operational security. A breach or breakdown of our systems that results
in the unauthorized release of individually identifiable customer or other sensitive data could have an adverse effect on our
reputation, results of operations and financial condition and could also materially increase our costs of maintaining our system
and protecting it against future breakdowns or breaches. We take reasonable precautions to safeguard our information systems
from cyber-attacks and security breaches; however, there is no guarantee that the procedures implemented to protect against
unauthorized access to our information systems are adequate to safeguard against all attacks and breaches. We also cannot
assure that any redundancies built into our networks and technology, or the procedures we have implemented to protect against
cyber-attacks and other unauthorized access to secured data, are adequate to safeguard against all failures of technology or
security breaches.
Chesapeake Utilities Corporation 2021 Form 10-K Page 17
Failure to attract and retain an appropriately qualified employee workforce could adversely affect operations.
Our ability to implement our business strategy and serve our customers depends upon our continuing ability to attract, develop
and retain talented professionals and a technically skilled workforce, and transfer the knowledge and expertise of our workforce
to new employees as our existing employees retire. Failure to hire and adequately train replacement employees, including the
transfer of significant internal historical knowledge and expertise to new employees, or the future availability and cost of
contract labor could adversely affect our ability to manage and operate our business. If we were unable to hire, train and retain
appropriately qualified personnel, our results of operations could be adversely affected.
A strike, work stoppage or a labor dispute could adversely affect our operations.
We are party to collective bargaining agreements with labor unions at some of our Florida operations. A strike, work stoppage
or a labor dispute with a union or employees represented by a union could cause interruption to our operations and our results
could be adversely affected.
Mandatory COVID-19 vaccination of employees or testing of employees could impact our workforce and have a material
adverse effect on our business and results of operations.
On September 9, 2021, President Biden issued an executive order (the “Executive Order”) requiring most employers with
U.S. Government contracts to ensure that their U.S.-based employees, contractors, and subcontractors, that work on or in
support of U.S. Government contracts, be fully vaccinated by December 8, 2021.This date was later postponed to January 4,
2022, to allow for the final dose of the vaccine to be administered. However, a number of federal district courts enjoined the
enforcement of this federal contractor mandate. As such, the federal government cannot, at present, enforce the Executive
Order and its vaccine mandate against federal contractors. The various district court orders enjoining enforcement are being
appealed by the federal government.
At this time, it is not possible to predict with certainty the nature and extent to which we will be subject to the Executive Order,
or impact the Executive Order will have on us or on our workforce. Additional vaccine mandates may be announced in other
jurisdictions in which we operate, or by governmental agencies with which we provide services. Implementation of these
requirements by us may result in employee attrition, including attrition of critically skilled labor, absenteeism within our skilled
labor force, challenges securing future labor needs, inefficiencies connected to employee turnover, and costs associated with
implementation and on-going compliance, which could have a material adverse effect on our business, financial condition and
results of operations.
Our businesses are capital-intensive, and the increased costs and/or delays of capital projects may adversely affect our future
earnings.
Our businesses are capital-intensive and require significant investments in ongoing infrastructure projects. Our ability to
complete our infrastructure projects on a timely basis and manage the overall cost of those projects may be affected by the
availability of the necessary materials and qualified vendors. Our future earnings could be adversely affected if we are unable
to manage such capital projects effectively, or if full recovery of such capital costs is not permitted in future regulatory
proceedings.
Our regulated energy business may be at risk if franchise agreements are not renewed, or new franchise agreements are
not obtained, which could adversely affect our future results or operating cash flows and financial condition.
Our regulated natural gas and electric distribution operations hold franchises in each of the incorporated municipalities that
require franchise agreements in order to provide natural gas and electricity. Ongoing financial results would be adversely
impacted in the event that franchise agreements were not renewed. If we are unable to obtain franchise agreements for new
service areas, growth in our future earnings could be negatively impacted.
Chesapeake Utilities Corporation 2021 Form 10-K Page 18
Slowdowns in customer growth may adversely affect earnings and cash flows.
Our ability to increase revenues in our natural gas, propane and electric distribution businesses is dependent upon growth in
the residential construction market, adding new commercial and industrial customers and conversion of customers to natural
gas, electricity or propane from other energy sources. Slowdowns in growth may adversely affect our results of operations,
cash flows and financial condition.
Energy conservation could lower energy consumption, which would adversely affect our earnings.
Federal and state legislative and regulatory initiatives to promote energy efficiency, conservation and the use of alternative
energy sources could lower energy consumption by our customers. In addition, higher costs of natural gas, propane and
electricity may cause customers to conserve fuel. To the extent a PSC or the FERC does not allow the recovery through customer
rates of higher costs or lower consumption from energy efficiency or conservation, and our propane retail prices cannot be
increased due to market conditions, our results of operations, cash flows and financial condition may be adversely affected.
Commodity price increases may adversely affect the operating costs and competitive positions of our natural gas, electric
and propane operations, which may adversely affect our results of operations, cash flows and financial condition.
Natural Gas/Electricity. Higher natural gas prices can significantly increase the cost of gas billed to our natural gas customers.
Increases in the cost of natural gas and other fuels used to generate electricity can significantly increase the cost of electricity
billed to our electric customers. Damage to the production or transportation facilities of our suppliers, which decreases their
supply of natural gas and electricity, could result in increased supply costs and higher prices for our customers. Such cost
increases generally have no immediate effect on our revenues and net income because of our regulated fuel cost recovery
mechanisms. However, our net income may be reduced by higher expenses that we may incur for uncollectible customer
accounts and by lower volumes of natural gas and electricity deliveries when customers reduce their consumption. Therefore,
increases in the price of natural gas and other fuels can adversely affect our operating cash flows, results of operations and
financial condition, as well as the competitiveness of natural gas and electricity as energy sources.
Propane. Propane costs are subject to changes as a result of product supply or other market conditions, including weather,
economic and political factors affecting crude oil and natural gas supply or pricing. For example, weather conditions could
damage production or transportation facilities, which could result in decreased supplies of propane, increased supply costs and
higher prices for customers. Such increases in costs can occur rapidly and can negatively affect profitability. There is no
assurance that we will be able to pass on propane cost increases fully or immediately, particularly when propane costs increase
rapidly. Therefore, average retail sales prices can vary significantly from year-to-year as product costs fluctuate in response to
propane, fuel oil, crude oil and natural gas commodity market conditions. In addition, in periods of sustained higher commodity
prices, declines in retail sales volumes due to reduced consumption and increased amounts of uncollectible accounts may
adversely affect net income.
Refer to Item 7A, Quantitative and Qualitative Disclosures about Market Risk for additional information.
A substantial disruption or lack of growth in interstate natural gas pipeline transmission and storage capacity or electric
transmission capacity may impair our ability to meet customers’ existing and future requirements.
In order to meet existing and future customer demands for natural gas and electricity, we must acquire sufficient supplies of
natural gas and electricity, interstate pipeline transmission and storage capacity, and electric transmission capacity to serve such
requirements. We must contract for reliable and adequate upstream transmission capacity for our distribution systems while
considering the dynamics of the interstate pipeline and storage and electric transmission markets, our own on-system resources,
as well as the characteristics of our markets. Our financial condition and results of operations would be materially and adversely
affected if the future availability of these capacities were insufficient to meet future customer demands for natural gas and
electricity. Currently, our Florida natural gas operation relies primarily on two pipeline systems, FGT and Peninsula Pipeline,
our intrastate pipeline subsidiary for most of its natural gas supply and transmission. Our Florida electric operation secures
electricity from external parties. Any continued interruption of service from these suppliers could adversely affect our ability
to meet the demands of our customers, which could negatively impact our earnings, financial condition and results of
operations.
Chesapeake Utilities Corporation 2021 Form 10-K Page 19
Our use of derivative instruments may adversely affect our results of operations.
Fluctuating commodity prices may affect our earnings and financing costs because our propane operations use derivative
instruments, including forwards, futures, swaps, puts, and calls, to hedge price risk. While we have risk management policies
and operating procedures in place to control our exposure to risk, if we purchase derivative instruments that are not properly
matched to our exposure, our results of operations, cash flows, and financial condition may be adversely affected.
Our ability to grow our businesses could be adversely affected if we are not successful in making acquisitions or integrating
the acquisitions we have completed.
One of our strategies is to grow through acquisitions of complementary businesses. Acquisitions involve a number or risks
including, but not limited to, the assumption of material liabilities, the diversion of management’s attention from the
management of daily operations to the integration of operations, difficulties in the assimilation and retention of employees and
difficulties in the assimilation of different cultures and internal controls. Future acquisitions could also result in, among other
things, the failure to identify material issues during due diligence, the risk of overpaying for assets, unanticipated capital
expenditures, the failure to maintain effective internal control over financial reporting, recording goodwill and other intangible
assets at values that ultimately may be subject to impairment charges and fluctuations in quarterly results. There can also be no
assurance that our past and future acquisitions will deliver the strategic, financial and operational benefits that we anticipate.
The failure to successfully integrate acquisitions could have an adverse effect on our results of operations, cash flows and
financial condition.
An impairment of goodwill could result in a significant charge to earnings.
In accordance with GAAP, goodwill is tested for impairment annually or whenever events or changes in circumstances indicate
impairment may have occurred. If the testing performed indicates that impairment has occurred, we are required to record an
impairment charge for the difference between the carrying value of the goodwill and the implied fair value of the goodwill in
the period the determination is made. The testing of goodwill for impairment requires us to make significant estimates about
our future performance and cash flows, as well as other assumptions. These estimates can be affected by numerous factors,
including: future business operating performance, changes in economic conditions and interest rates, regulatory, industry or
market conditions, changes in business operations, changes in competition or changes in technologies. Any changes in key
assumptions, or actual performance compared with key assumptions, about our business and its future prospects could affect
the fair value of one or more business segments, which may result in an impairment charge.
REGULATORY, LEGAL AND ENVIRONMENTAL RISKS
Regulation of our businesses, including changes in the regulatory environment, may adversely affect our results of
operations, cash flows and financial condition.
The Delaware, Maryland and Florida PSCs regulate our utility operations in those states. Eastern Shore is regulated by the
FERC. The PSCs and the FERC set the rates that we can charge customers for services subject to their regulatory jurisdiction.
Our ability to obtain timely rate increases and rate supplements to maintain current rates of return depends on regulatory
approvals, and there can be no assurance that our regulated operations will be able to obtain such approvals or maintain currently
authorized rates of return. When earnings from our regulated utilities exceed the authorized rate of return, the respective
regulatory authority may require us to reduce our rates charged to customers in the future.
We may face certain regulatory and financial risks related to pipeline safety legislation.
We are subject to a number of legislative proposals at the federal and state level to implement increased oversight over natural
gas pipeline operations and facilities to inspect pipeline facilities, upgrade pipeline facilities, or control the impact of a breach
of such facilities. Additional operating expenses and capital expenditures may be necessary to remain in compliance. If new
legislation is adopted and we incur additional expenses and expenditures, our financial condition, results of operations and cash
flows could be adversely affected, particularly if we are not authorized through the regulatory process to recover from customers
some or all of these costs and our authorized rate of return.
Chesapeake Utilities Corporation 2021 Form 10-K Page 20
We are subject to operating and litigation risks that may not be fully covered by insurance.
Our operations are subject to the operating hazards and risks normally incidental to handling, storing, transporting, transmitting
and delivering natural gas, electricity and propane to end users. From time to time, we are a defendant in legal proceedings
arising in the ordinary course of business. We maintain insurance coverage for our general liabilities in the amount of $52
million, which we believe is reasonable and prudent. However, there can be no assurance that such insurance will be adequate
to protect us from all material expenses related to potential future claims for personal injury and property damage or that such
levels of insurance will be available in the future at economical prices.
Costs of compliance with environmental laws may be significant.
We are subject to federal, state and local laws and regulations governing environmental quality and pollution control. These
evolving laws and regulations may require expenditures over a long period of time to control environmental effects at our
current and former operating sites, especially former MGP sites. To date, we have been able to recover, through regulatory rate
mechanisms, the costs associated with the remediation of former MGP sites. However, there is no guarantee that we will be
able to recover future remediation costs in the same manner or at all. A change in our approved rate mechanisms for recovery
of environmental remediation costs at former MGP sites could adversely affect our results of operations, cash flows and
financial condition.
Further, existing environmental laws and regulations may be revised, or new laws and regulations seeking to protect the
environment may be adopted and be applicable to us. Revised or additional laws and regulations could result in additional
operating restrictions on our facilities or increased compliance costs, which may not be fully recoverable. Any such increase in
compliance costs could adversely affect our financial condition and results of operations. Compliance with these legal
obligations requires us to commit capital. If we fail to comply with environmental laws and regulations, even if such failure is
caused by factors beyond our control, we may be assessed civil or criminal penalties and fines, which could impact our financial
condition and results of operations. See Item 8, Financial Statements and Supplementary Data (see Note 20, Environmental
Commitments and Contingencies, in the consolidated financial statements).
Unanticipated changes in our tax provisions or exposure to additional tax liabilities could affect our profitability and cash
flow.
We are subject to income and other taxes in the U.S. and the states in which we operate. Changes in applicable state or U.S. tax
laws and regulations, or their interpretation and application, including the possibility of retroactive effect, could affect our tax
expense and profitability. In addition, the final determination of any tax audits or related litigation could be materially different
from our historical income tax provisions and accruals. Changes in our tax provision or an increase in our tax liabilities, due to
changes in applicable law and regulations, the interpretation or application thereof, future changes in the tax rate or a final
determination of tax audits or litigation, could have a material adverse effect on our financial position, results of operations or
cash flows.
Our business may be subject in the future to additional regulatory and financial risks associated with global warming and
climate change.
There have been a number of federal and state legislative and regulatory initiatives proposed in recent years in an attempt to
control or limit the effects of global warming and overall climate change, including greenhouse gas emissions, such as carbon
dioxide. The direction of future U.S. climate change regulation is difficult to predict given the potential for policy changes
under different Presidential administrations and Congressional leadership. The EPA may or may not continue developing
regulations to reduce greenhouse gas emissions. Even if federal efforts in this area slow, states, cities and local jurisdictions
may continue pursuing climate regulations. Any laws or regulations that may be adopted to restrict or reduce emissions of
greenhouse gases could require us to incur additional operating costs, such as costs to purchase and operate emissions controls,
to obtain emission allowances or to pay emission taxes, and reduce demand for our energy delivery services. Federal, state and
local legislative initiatives to implement renewable portfolio standards or to further subsidize the cost of solar, wind and other
renewable power sources may change the demand for natural gas. We cannot predict the potential impact that such laws or
regulations, if adopted, may have on our future business, financial condition or financial results.
Chesapeake Utilities Corporation 2021 Form 10-K Page 21
Climate changes may impact the demand for our services in the future and could result in more frequent and more severe
weather events, which ultimately could adversely affect our financial results.
Significant climatic change creates physical and financial risks for us. Our customers' energy needs vary with weather
conditions, primarily temperature and humidity. For residential customers, heating and cooling represent their largest energy
use. To the extent weather conditions may be affected by climate change, customers' energy use could increase or decrease
depending on the duration and magnitude of any changes. To the extent that climate change adversely impacts the economic
health or weather conditions of our service territories directly, it could adversely impact customer demand or our customers’
ability to pay. Changes in energy use due to weather variations may affect our financial condition through volatility and/or
decreased revenues and cash flows. Extreme weather conditions require more system backups and can increase costs and system
stresses, including service interruptions. Severe weather impacts our operating territories primarily through thunderstorms,
tornadoes, hurricanes, and snow or ice storms. Weather conditions outside of our operating territories could also have an impact
on our revenues and cash flows by affecting natural gas prices. To the extent the frequency of extreme weather events increases,
this could increase our costs of providing services. We may not be able to pass on the higher costs to our customers or recover
all the costs related to mitigating these physical risks. To the extent financial markets view climate change and emissions of
greenhouse gases as a financial risk, this could adversely affect our ability to access capital markets or cause us to receive less
favorable terms and conditions in future financings. Our business could be affected by the potential for investigations and
lawsuits related to or against greenhouse gas emitters based on the claimed connection between greenhouse gas emissions and
climate change, which could impact adversely our business, results of operations and cash flows.
We face risks related to widespread public concerns, including the COVID-19 outbreak.
The actual or perceived effects of a disease outbreak, epidemic, pandemic or similar widespread public health concern, such as
COVID-19, could negatively affect our operations, liquidity, financial condition, cash flows and results of operations. The
outbreak of COVID-19 has adversely impacted economic activity and conditions worldwide. In particular, efforts to control
the spread of COVID-19 led to shutdowns of customer operations and disrupted financial markets and supply chains.
We continue to respond to COVID-19 by taking steps to mitigate the impact of its spread and the potential risks to us. We
provide a critical service to our customers, which means that it is paramount that we keep our employees who operate our
businesses safe and minimize unnecessary risk of the exposure to COVID-19. We continue to operate under our Pandemic
Response Plan that dates back to 2007. This plan guides our emergency response, business continuity, and the precautionary
measures we have been taking on behalf of our employees, our customers and the communities we serve. We continue to take
extra precautions for our employees who work in the field and for employees who continue to work in our facilities, and we
have maintained work from home policies where appropriate. We continue to operate under restricted travel plans, minimize
movement between offices, utilize virtual, or on-line work, meetings and events, and employ “social distancing” as directed
by the CDC and state and local governments in the areas we serve. We have suspended walk-in customer access to our natural
gas, propane and electric offices, and reminded customers of our online and direct mail payment options. We continue to utilize
multiple organizational teams and task forces to guide us through ever changing key aspects of this pandemic. We have
instituted measures to ensure our supply chains remain open to us; however, there could be global shortages that will impact
our maintenance and capital programs that we currently cannot anticipate. We will continue to monitor developments affecting
our workforce, our customers and our suppliers, and we will take additional precautions that we determine are necessary in
order to mitigate the impacts. We continue to implement measures to ensure that our systems remain functional in order to both
serve our operational needs with a remote workforce and keep them running to ensure uninterrupted service to our customers.
To date, the crisis has not had a material effect on the Company.
The extent to which COVID-19 impacts our future results, financial position and liquidity will depend on many factors. At the
present time, not all of these factors can be predicted, including new information, which may emerge concerning the severity
and duration of the pandemic or any subsequent mutations, the actions mandated by governmental authorities to contain
COVID-19 and the availability and timing to identified vaccines, among others.
Chesapeake Utilities Corporation 2021 Form 10-K Page 22
Additional risks and uncertainties not known to us at present, or that we currently deem immaterial, also may affect Chesapeake
Utilities. The occurrence of any of these known or unknown risks could have a material adverse impact on our business,
financial condition and results of operations.
Our certificate of incorporation and bylaws may delay or prevent a transaction that stockholders would view as favorable.
Our certificate of incorporation and bylaws, as well as Delaware law, contain provisions that could delay, defer or prevent an
unsolicited change in control of Chesapeake Utilities, which may negatively affect the market price of our common stock or
the ability of stockholders to participate in a transaction in which they might otherwise receive a premium for their shares over
the then current market price. These provisions may also prevent changes in management. In addition, our Board of Directors
is authorized to issue preferred stock without stockholder approval on such terms as our Board of Directors may determine.
Our common stockholders will be subject to, and may be negatively affected by, the rights of any preferred stock that may be
issued in the future.
ITEM 1B. UNRESOLVED STAFF COMMENTS.
None.
ITEM 2. Properties.
Offices and other operational facilities
We own or lease offices and other operational facilities in our service territories located in Delaware, Maryland, Virginia, North
Carolina, South Carolina, Florida, Pennsylvania and Ohio.
Regulated Energy Segment
The following table presents a summary of miles of assets operated by our natural gas distribution, natural gas transmission
and electric business units as of December 31, 2021:
Operations
Natural Gas Distribution
Delmarva Natural Gas (Natural gas pipelines)
Delmarva Natural Gas (Underground propane pipelines)
Central Florida Gas and FPU (Natural gas pipelines)
Natural Gas Transmission
Eastern Shore
Peninsula Pipeline
Aspire Energy Express (1)
Electric Distribution
FPU
Total
Miles
1,934
32
3,030
516
144
—
906
6,562
Chesapeake Utilities Corporation 2021 Form 10-K Page 23
(1) Aspire Energy Express had less than 1 mile of natural gas pipeline at December 31, 2021.
Peninsula Pipeline also has a 50 percent jointly owned intrastate transmission pipeline with Seacoast Gas Transmission, LLC
("Seacoast Gas Transmission") in Nassau County, Florida. The 26-mile pipeline will serve growing demand in both Nassau
and Duval Counties.
Unregulated Energy Segment
As of December 31, 2021 the following table presents propane storage capacity, miles of underground distribution mains and
transmission for our Unregulated Energy Segment operations:
Operations
Propane distribution
Propane storage capacity (gallons in millions)
Underground propane distribution mains (miles)
Unregulated Energy Transmission and gathering (Aspire Energy)
Natural gas pipelines (miles)
Gallons or miles
8.9
198
2,800
ITEM 3. Legal Proceedings.
See Note 21, Other Commitments and Contingencies in the Consolidated Financial Statements, which is incorporated into Item
3 by reference.
ITEM 4. Mine Safety Disclosures.
Not applicable.
PART II
ITEM 5. Market for the Registrant's Common Equity, Related Stockholder Matters and Issuer Purchases of Equity
Securities.
Common Stock Dividends and Stockholder Information:
Chesapeake Utilities common stock is traded on the New York Stock Exchange ("NYSE") under the ticker symbol CPK. As of
February 18, 2022, we had 2,075 holders of record of our common stock. We declared quarterly cash dividends on our common
stock totaling $1.880 per share in 2021 and $1.725 per share in 2020, and have paid a cash dividend to our common stock
stockholders for 61 consecutive years. Future dividend payments and amounts are at the discretion of our Board of Directors
and will depend on our financial condition, results of operations, capital requirements, and other factors.
Indentures to our long-term debt contain various restrictions which limit our ability to pay dividends. Refer to Item 8, Financial
Statements and Supplementary Data (see Note 13, Long-Term Debt, in the consolidated financial statements) for additional
information.
Chesapeake Utilities Corporation 2021 Form 10-K Page 24
Purchases of Equity Securities by the Issuer
The following table sets forth information on purchases by us or on our behalf of shares of our common stock during the quarter
ended December 31, 2021.
Period
October 1, 2021 through October 31, 2021 (1)
November 1, 2021 through November 30, 2021
December 1, 2021 through December 31, 2021
Total
Total
Number
of Shares
Purchased
Average
Price Paid
per Share
Total Number of Shares
Purchased as Part of
Publicly Announced Plans
or Programs (2)
Maximum Number of
Shares That May Yet Be
Purchased Under the Plans
or Programs (2)
431 $
—
—
431 $
128.24
—
—
128.24
—
—
—
—
—
—
—
—
(1) In October 2021, we purchased 431 shares of common stock on the open market for the purpose of reinvesting the dividend on shares held in the Rabbi
Trust accounts under the Non-Qualified Deferred Compensation Plan. The Non-Qualified Deferred Compensation Plan is discussed in detail in Item 8,
Financial Statements and Supplementary Data (see Note 17, Employee Benefit Plans, in the consolidated financial statements).
(2) Except for the purpose described in footnote (1), we have no publicly announced plans or programs to repurchase our shares.
Discussion of our compensation plans, for which shares of our common stock are authorized for issuance, is included in the
section of our Proxy Statement captioned “Equity Compensation Plan Information” and is incorporated herein by reference.
Chesapeake Utilities Corporation 2021 Form 10-K Page 25
Common Stock Performance Graph
The stock performance graph and table below compares cumulative total stockholder return on our common stock during the
five fiscal years ended December 31, 2021, with the cumulative total stockholder return of the Standard & Poor’s 500 Index
and the cumulative total stockholder return of select peers, which include the following companies: Atmos Energy Corporation;
Black Hills Corporation; New Jersey Resources Corporation; NiSource Inc.; Northwest Natural Holding Company;
NorthWestern Corporation; ONE Gas Inc.; RGC Resources, Inc.; South Jersey Industries, Inc.; Spire Inc. and Unitil
Corporation.
The comparison assumes $100 was invested on December 31, 2016 in our common stock and in each of the foregoing indices
and assumes reinvested dividends. The comparisons in the graph below are based on historical data and are not intended to
forecast the possible future performance of our common stock.
2016
2017
2018
2019
2020
2021
Chesapeake Utilities
Industry Index
S&P 500 Index
$
$
$
100 $
100 $
100 $
119 $
114 $
122 $
126 $
122 $
116 $
151 $
170 $
153 $
174 $
121 $
181 $
237
160
233
Chesapeake Utilities Corporation 2021 Form 10-K Page 26
ITEM 6. [RESERVED]
ITEM 7. Management's Discussion and Analysis of Financial Condition and Results of Operations
This section provides management’s discussion of Chesapeake Utilities and its consolidated subsidiaries, with specific
information on results of operations, liquidity and capital resources, as well as discussion of how certain accounting principles
affect our financial statements. It includes management’s interpretation of our financial results and our operating segments, the
factors affecting these results, the major factors expected to affect future operating results as well as investment and financing
plans. This discussion should be read in conjunction with our consolidated financial statements and notes thereto in Item 8,
Financial Statements and Supplementary Data.
Several factors exist that could influence our future financial performance, some of which are described in Item 1A, Risk Factors.
They should be considered in connection with forward-looking statements contained in this Annual Report, or otherwise made
by or on behalf of us, since these factors could cause actual results and conditions to differ materially from those set out in such
forward-looking statements.
In March 2020, the CDC declared a national emergency due to the rapidly growing outbreak of COVID-19. In response to this
declaration and the rapid spread of COVID-19 within the United States, federal, state and local governments throughout the
country imposed varying degrees of restrictions on social and commercial activity to promote social distancing in an effort to
slow the spread of the illness. These restrictions significantly impacted economic conditions in the United States in 2020 and
continued in some capacity throughout all of 2021. Chesapeake Utilities is considered an “essential business,” which has allowed
us to continue operational activities and construction projects while adhering to the social distancing restrictions that were in
place.
Throughout 2021, restrictions continued to be lifted as vaccines have become widely available in the United States. For example,
the state of emergency in Florida was terminated in May 2021 followed by Delaware and Maryland in July 2021, resulting in
reduced restrictions. The expiration of the states of emergency in our service territories, along with the settlement of our limited
proceeding in Florida, has concluded our ability to defer incremental pandemic related costs for consideration through the
applicable regulatory process.
We have been closely following the legal process related to the Occupational Safety and Health Administration (OSHA)
Emergency Temporary Standard (ETS) mandating that all employers, with 100 or more employees, require COVID-19
vaccinations or weekly testing, which made its way to the United States Supreme Court. While OSHA has withdrawn the ETS as
a temporary standard following the Supreme Court’s ruling, we will continue to monitor its status as a proposed rule. In light of
the continued emergence and growing prevalence of the new variants of COVID-19, such as the Omicron variant, we continue
to operate under our pandemic response plan, monitor developments affecting employees, customers, suppliers, and stockholders
and take all precautions warranted to operate safely and to comply with the CDC and OSHA standards, in order to protect our
employees, customers and the communities we serve. Refer to Item 8, Financial Statements and Supplementary Data, Note 19,
Rates and Other Regulatory Activities, for further information on the potential deferral of incremental expenses associated with
COVID-19.
Earnings per share information is presented on a diluted basis, unless otherwise noted.
The following discussions and those later in the document on operating income and segment results include the use of the term
Adjusted Gross Margin which is a non-GAAP measure throughout our discussion on operating results. Adjusted Gross Margin is
calculated by deducting the purchased cost of natural gas, propane and electricity and the cost of labor spent on direct revenue-
producing activities from operating revenues. The costs included in Adjusted Gross Margin exclude depreciation and amortization
and certain costs presented in operations and maintenance expenses in accordance with regulatory requirements. Adjusted Gross
Margin should not be considered an alternative to Gross Margin under U.S. GAAP which is defined as the excess of sales over
cost of goods sold. We believe that Adjusted Gross Margin, although a non-GAAP measure, is useful and meaningful to investors
as a basis for making investment decisions. It provides investors with information that demonstrates the profitability achieved by
Chesapeake Utilities Corporation 2021 Form 10-K Page 27
us under our allowed rates for regulated energy operations and under our competitive pricing structures for our unregulated
energy operations. Our management uses Adjusted Gross Margin as one of the financial measures in assessing our business units’
performance. Other companies may calculate Adjusted Gross Margin in a different manner.
The below tables reconcile Gross Margin as defined under GAAP to our non-GAAP measure of Adjusted Gross Margin for the
years ended December 31, 2021, 2020 and 2019:
(in thousands)
Operating Revenues
Cost of Sales:
For the Year Ended December 31, 2021
Regulated Energy
$
383,920 $
Unregulated
Energy
Other and
Eliminations
Total
206,869 $
(20,821) $
569,968
Natural gas, propane and
electric costs
Depreciation & amortization
Operations & maintenance
expense (1)
Gross Margin (GAAP)
Operations & maintenance
expense (1)
Depreciation & amortization
Adjusted Gross Margin (Non-
GAAP)
$
(100,737)
(48,748)
(32,890)
201,545
32,890
48,748
(106,900)
(13,869)
(24,168)
61,932
24,168
13,869
20,686
(44)
334
155
(334)
44
(186,951)
(62,661)
(56,724)
263,632
56,724
62,661
283,183 $
99,969 $
(135) $
383,017
(in thousands)
Operating Revenues
Cost of Sales:
For the Year Ended December 31, 2020
Regulated Energy
$
352,746 $
Unregulated
Energy
Other and
Eliminations
Total
152,526 $
(17,074) $
488,198
Natural gas, propane and
electric costs
Depreciation & amortization
Operations & maintenance
expense (1)
Gross Margin (GAAP)
Operations & maintenance
expense (1)
Depreciation & amortization
Adjusted Gross Margin (Non-
GAAP)
$
(91,994)
(46,079)
(31,237)
183,436
31,237
46,079
(62,780)
(11,988)
(22,914)
54,844
22,914
11,988
16,836
(50)
298
10
(298)
50
(137,938)
(58,117)
(53,853)
238,290
53,853
58,117
260,752 $
89,746 $
(238) $
350,260
Chesapeake Utilities Corporation 2021 Form 10-K Page 28
(in thousands)
Operating Revenues
Cost of Sales:
For the Year Ended December 31, 2019
Regulated Energy
$
343,006 $
Unregulated
Energy
Other and
Eliminations
Total
154,150 $
(17,551) $
479,605
Natural gas, propane and
electric costs
Depreciation & amortization
Operations & maintenance
expense (1)
Gross Margin (GAAP)
Operations & maintenance
expense (1)
Depreciation & amortization
Adjusted Gross Margin (Non-
GAAP)
(102,803)
(35,227)
(30,219)
174,757
30,219
35,227
(68,885)
(10,130)
(22,025)
53,110
22,025
10,130
17,187
(67)
334
(97)
(334)
67
(154,501)
(45,424)
(51,910)
227,770
51,910
45,424
$
240,203 $
85,265 $
(364) $
325,104
(1) Operations & maintenance expenses within the Consolidated Statements of Income are presented in accordance with
regulatory requirements and to provide comparability within the industry. Operations & maintenance expenses which are deemed
to be directly attributable to revenue producing activities have been separately presented above in order to calculate Gross
Margin as defined under U.S. GAAP.
2021 to 2020 Gross Margin (GAAP) Variance – Regulated Energy
Gross Margin (GAAP) for the Regulated Energy segment for 2021 was $201.5 million, an increase of $18.1 million, or 9.9
percent, compared to 2020. Higher operating gross margin reflects continued pipeline expansions by Eastern Shore and Peninsula
Pipeline, organic growth in the natural gas distribution businesses, increased consumption from a return toward pre-pandemic
consumption levels and operating results from 2020 and 2021 acquisitions. These increases were partially offset by higher
depreciation, amortization related to recent capital investments and acquisitions, increased payroll and benefits costs as well as
operating expenses associated with a return toward pre-pandemic conditions.
2020 to 2019 Gross Margin (GAAP) Variance – Regulated Energy
Gross Margin (GAAP) for the Regulated Energy segment for 2020 was $183.4 million, an increase of $8.7 million, or 5.0 percent,
compared to 2019. In the fourth quarter of 2020, we established $1.9 million of regulatory assets based on the estimated net
incremental expense resulting from the COVID-19 pandemic for our natural gas distribution and electric businesses as currently
authorized by the Delaware, Maryland and Florida PSCs. Excluding the estimated unfavorable COVID-19 impacts of $4.2 million
for the year, Gross Margin (GAAP) increased $12.9 million as a result of the Hurricane Michael regulatory proceeding settlement,
operating results from expansion projects completed by Eastern Shore and Peninsula Pipeline, organic growth in our natural gas
distribution businesses, contribution from the Elkton Gas acquisition and additional GRIP investments. These increases were
offset by lower customer consumption driven primarily by milder weather; higher depreciation and amortization, including
amortization of the regulatory asset associated with the Hurricane Michael regulatory proceeding settlement, new expenses
associated with the acquisition of Elkton Gas, and higher other operating expenses.
2021 to 2020 Gross Margin (GAAP) Variance – Unregulated Energy
Gross Margin (GAAP) for the Unregulated Energy segment for 2021 was $61.9 million, an increase of $7.1 million compared to
2020. Higher gross margin is a result of weather that was colder than 2020, higher retail propane margins per gallon and service
fees, contributions from the propane acquisitions completed in 2020 and 2021, increased demand for Marlin Gas Services' CNG
transportation services and increased customer consumption along with higher rates for Aspire Energy. These increases were
Chesapeake Utilities Corporation 2021 Form 10-K Page 29
partially offset by higher depreciation, amortization and property taxes related to recent capital investments and acquisitions, a
return toward pre-pandemic conditions and a general increase in operating expenses to support growth in the business.
2020 to 2019 Gross Margin (GAAP) Variance – Unregulated Energy
Gross Margin (GAAP) for the Unregulated Energy segment for 2020 was $54.8 million, an increase of $1.7 million compared to
2019. Excluding the estimated COVID-19 impacts of $1.7 million, Gross Margin (GAAP) increased $3.4 million due to the
acquisitions of the Boulden and Western Natural Gas propane assets, higher retail propane volumes and fees, increased demand
for Marlin Gas Services’ CNG transportation services and higher rates for Aspire Energy. These increases were partially offset
by reduced volumes from overall warmer temperatures and higher depreciation and amortization expenses associated with recent
acquisitions.
OVERVIEW AND HIGHLIGHTS
(in thousands except per share data)
For the Year Ended December 31,
Business Segment:
Regulated Energy
Unregulated Energy
Other businesses and eliminations
Operating Income
Other income (expense), net
Interest charges
Income from Continuing Operations
Before Income Taxes
Income Taxes on Continuing Operations
Income from Continuing Operations
Income (loss) from Discontinued Operations,
Net of Tax
Gain on sale of Discontinued Operations, Net
of tax
Net Income
Basic Earnings Per Share of Common
Stock
Earnings Per Share from Continuing
Operations
Earnings/ Per Share from Discontinued
Operations
Basic Earnings Per Share of Common Stock
Diluted Earnings Per Share of Common
Stock:
Earnings Per Share from Continuing
Operations
Earnings Per Share from Discontinued
Operations
2021
2020
Increase
(decrease)
2020
2019
Increase
(decrease)
$ 106,064 $ 92,124 $ 13,940 $ 92,124 $ 86,584 $
3,718
24,382
666
131,112
1,721
20,135
112,698
29,231
83,467
(1)
—
20,664
(65)
112,723
3,222
21,765
94,180
23,538
70,642
686
170
20,664
(65)
112,723
3,222
21,765
94,180
23,538
70,642
686
170
731
18,389
(1,501)
(1,630)
18,518
5,693
12,825
(687)
(170)
19,938
(237)
106,285
(1,847)
22,224
5,540
726
172
6,438
5,069
(459)
82,214
21,114
61,100
11,966
2,424
9,542
(1,349)
2,035
5,402
(5,232)
6,345
$ 83,466 $ 71,498 $ 11,968 $ 71,498 $ 65,153 $
$
4.75 $
4.23 $
0.52 $
4.23 $
3.73 $
0.50
—
0.05
$
4.75 $
4.28 $
(0.05)
0.47 $
0.05
0.24
4.28 $
3.97 $
(0.19)
0.31
$
4.73 $
4.21 $
0.52 $
4.21 $
3.72 $
0.49
—
0.05
(0.05)
0.47 $
0.05
0.24
4.26 $
3.96 $
(0.19)
0.30
Diluted Earnings Per Share of Common Stock $
4.73 $
4.26 $
Chesapeake Utilities Corporation 2021 Form 10-K Page 30
2021 compared to 2020
Key variances in continuing operations between 2021 and 2020 included:
(in thousands, except per share data)
Year ended December 31, 2020 Reported Results from Continuing Operations
Adjusting for unusual items:
Gains from sales of assets
Net impact of NOL Carryback related to implementation of the CARES Act
Reduced interest expense related to early extinguishment of FPU mortgage bonds
Regulatory deferral of COVID-19 expenses per PSCs orders
Increased (Decreased) Adjusted Gross Margins:
Eastern Shore and Peninsula Pipeline service expansions*
Increased customer consumption - primarily weather related
Contributions from 2020 and 2021 acquisitions*
Increased propane margins per gallon and fees
Increased customer consumption - primarily due to return to pre-pandemic
consumption
Contributions from regulated infrastructure programs *
Natural gas growth (excluding service expansions)
Improved performance from electric operations
Higher results from Aspire Energy
(Increased) Decreased Other Operating Expenses (Excluding Natural Gas,
Electricity and Propane Costs):
Depreciation, amortization and property tax costs due to new capital investments
Outside services due to growth and a return toward pre-pandemic conditions
Operating expenses from recent acquisitions
Payroll, benefits and other employee-related expenses
Increased facilities and maintenance costs
Pre-tax
Income
Net
Income
$
94,180
$
70,642 $
Earnings
Per Share
4.21
(989)
—
961
2,377
2,349
7,168
5,519
4,773
3,638
3,418
3,158
3,084
1,015
325
32,098
(5,995)
(3,403)
(2,914)
(1,756)
(1,130)
(15,198)
(724)
(919)
704
1,741
802
5,250
4,043
3,496
2,664
2,504
2,313
2,259
743
238
23,510
(4,391)
(2,493)
(2,134)
(1,286)
(828)
(11,132)
(0.04)
(0.05)
0.04
0.10
0.05
0.30
0.23
0.20
0.15
0.14
0.13
0.13
0.04
0.01
1.33
(0.25)
(0.14)
(0.12)
(0.07)
(0.05)
(0.63)
(0.21)
(0.02)
4.73
Change in shares outstanding due to 2020 and 2021 equity offerings
Net Other Changes
Year ended December 31, 2021 Reported Results from Continuing Operations
* See the Major Projects and Initiatives table.
—
(731)
112,698 $
—
(355)
83,467 $
$
Chesapeake Utilities Corporation 2021 Form 10-K Page 31
SUMMARY OF KEY FACTORS
Recently Completed and Ongoing Major Projects and Initiatives
We constantly pursue and develop additional projects and initiatives to serve existing and new customers, further grow our
businesses and earnings, with the intention of increasing shareholder value. The following represent the major projects/initiatives
recently completed and currently underway. In the future, we will add new projects and initiatives to this table once substantially
finalized and the associated earnings can be estimated.
Adjusted Gross Margin
(in thousands)
Pipeline Expansions:
Western Palm Beach County, Florida Expansion (1)
Del-Mar Energy Pathway (1) (2)
Callahan Intrastate Pipeline (2) (3)
Guernsey Power Station
Southern Expansion
Winter Haven Expansion
Beachside Pipeline Expansions
Total Pipeline Expansions
CNG Transportation
RNG Transportation
Acquisitions:
Diversified Energy
Elkton Gas
Western Natural Gas
Escambia Meter Station
Total Acquisitions
Regulatory Initiatives:
Florida GRIP
Hurricane Michael Regulatory Proceeding
Capital Cost Surcharge Programs
Elkton STRIDE Plan
Total Regulatory Initiatives
Year Ended December 31,
2020
2019
2021
Estimate for Fiscal
2023
2022
$
2,139 $
731
—
—
—
—
—
2,870
4,167 $
2,462
3,080
—
—
—
—
9,709
4,729 $
4,584
7,564
187
—
—
—
17,064
5,227 $
6,867
7,564
1,380
586
759
—
22,383
5,227
6,890
7,564
1,486
2,344
976
2,451
26,938
5,410
7,231
7,566
8,500
9,500
—
—
—
1,000
1,000
—
—
—
—
—
—
1,344
389
—
1,733
603
3,548
1,772
583
6,506
11,300
3,720
2,001
1,000
18,021
13,939
—
—
—
13,939
15,178
10,864
523
—
26,565
16,995
11,492
1,199
26
29,712
18,797
11,704
2,002
299
32,802
12,000
3,743
2,061
1,000
18,804
19,475
11,818
1,961
354
33,608
Total
(1) Includes adjusted gross margin generated from interim services.
(2) Includes adjusted gross margin from natural gas distribution services.
(3) Prior year amounts have been revised to conform to the current period presentation.
$
22,219 $
45,238 $
60,848 $
82,706 $
89,850
Chesapeake Utilities Corporation 2021 Form 10-K Page 32
Detailed Discussion of Major Projects and Initiatives
Pipeline Expansions
Western Palm Beach County, Florida Expansion
Peninsula Pipeline is constructing four transmission lines to bring additional natural gas to our distribution system in West Palm
Beach, Florida. The first phase of this project was placed into service in December 2018 and generated incremental adjusted gross
margin of $0.6 million during 2021 compared to 2020. The remainder of the project was completed in the fourth quarter of 2021.
We estimate that the project will generate annual adjusted gross margin of $5.2 million in 2022 and beyond.
Del-Mar Energy Pathway
In December 2019, the FERC issued an order approving the construction of the Del-Mar Energy Pathway project. The project
was placed into service in the fourth quarter of 2021. The new facilities: (i) include an additional 14,300 Dts/d of firm service to
four customers, (ii) provide additional natural gas transmission pipeline infrastructure in eastern Sussex County, Delaware, and
(iii) represent the first extension of Eastern Shore’s pipeline system into Somerset County, Maryland. Construction of the project
began in January 2020; including interim services in advance of construction completion, the project generated additional adjusted
gross margin of $2.1 million for the year ended December 31, 2021. The estimated annual adjusted gross margin from this project,
including natural gas distribution service in Somerset County, Maryland, is approximately $6.9 million in 2022 and growing each
year thereafter, as the distribution system serving Somerset County further expands to meet demand.
Callahan Intrastate Pipeline
In May 2018, Peninsula Pipeline announced a plan to construct a jointly owned 26-mile intrastate transmission pipeline with
Seacoast Gas Transmission in Nassau County, Florida to serve the growing demand in both Nassau and Duval Counties. This
project was placed in service in June 2020 and generated $4.5 million in additional adjusted gross margin for the year ended
December 31, 2021 including margin from natural gas distribution service. The pipeline is expected to generate $7.6 million
annually in adjusted gross margin in 2022 and beyond.
Guernsey Power Station
Guernsey Power Station and the Company's affiliate, Aspire Energy Express, entered into a precedent agreement for firm
transportation capacity whereby Guernsey Power Station will construct a power generation facility and Aspire Energy Express
will provide firm natural gas transportation service to this facility. Guernsey Power Station commenced construction of the project
in October 2019. Aspire Energy Express completed construction of the gas transmission facilities to provide the firm
transportation service to the power generation facility in the fourth quarter of 2021. This project is expected to produce adjusted
gross margin of approximately $1.4 million in 2022 and $1.5 million in 2023 and beyond.
Southern Expansion
Pending FERC authorization, Eastern Shore plans to install a new natural gas driven compressor skid unit at its existing
Bridgeville, Delaware compressor station that will provide 7,300 Dts of incremental firm transportation pipeline capacity. The
project is currently estimated to go into service in the fourth quarter of 2022. Eastern Shore expects the Southern Expansion
project to generate annual adjusted gross margin of $0.6 million in 2022 and $2.3 million in 2023 and thereafter.
Winter Haven Expansion
In May 2021, Peninsula Pipeline filed a petition with the Florida PSC for approval of its Transportation Service Agreement with
CFG for an incremental 6,800 Dts/d of firm service in the Winter Haven, Florida area. As part of this agreement, Peninsula
Pipeline will construct a new interconnect with FGT and a new regulator station for CFG. CFG will use the additional firm service
to support new incremental load due to growth in the area, including providing service, most immediately, to a new can
manufacturing facility, as well as reliability and operational benefits to CFG’s existing distribution system in the area. In
connection with Peninsula Pipeline’s new regulator station, CFG is also extending its distribution system to connect to the new
station. We expect this expansion to generate additional adjusted gross margin of $0.8 million beginning in 2022 and $1.0 million
in 2023 and beyond.
Chesapeake Utilities Corporation 2021 Form 10-K Page 33
Beachside Pipeline Expansion
In June 2021, Peninsula Pipeline and Florida City Gas entered into a Transportation Service Agreement for an incremental 10,176
Dts/d of firm service in Indian River County, Florida, to support Florida City Gas’ growth along the Indian River's barrier island.
As part of this agreement, Peninsula Pipeline will construct approximately 11.3 miles of pipeline from its existing pipeline in the
Sebastian, Florida, area east under the ICW and southward on the barrier island. We expect this expansion to generate additional
annual adjusted gross margin of $2.5 million in 2023 and beyond.
CNG Transportation
Marlin Gas Services provides CNG temporary hold services, contracted pipeline integrity services, emergency services for
damaged pipelines and specialized gas services for customers who have unique requirements. For the year ended December 31,
2021, Marlin Gas Services generated additional adjusted gross margin of $0.3 million compared to the year ended December 31,
2020. We estimate that Marlin Gas Services will generate annual adjusted gross margin of approximately $8.5 million in 2022,
and $9.5 million in 2023, with potential for additional growth in future years. Marlin Gas Services continues to actively expand
the territories it serves, as well as leverage its patented technology to serve other markets, including pursuing liquefied natural
gas transportation opportunities and renewable natural gas transportation opportunities from diverse supply sources to various
pipeline interconnection points, as further outlined below.
RNG Transportation
Noble Road Landfill RNG Project
In September 2020, Fortistar and Rumpke Waste & Recycling announced commencement of construction of the Noble Road
Landfill RNG Project in Shiloh, Ohio. The project includes the construction of a new state-of-the-art facility that will utilize
advanced, patented technology to treat landfill gas by removing carbon dioxide and other components to purify the gas and
produce pipeline quality RNG. In October 2021, we announced that Aspire Energy had completed construction of its Noble Road
Landfill RNG pipeline project, a 33.1-mile pipeline, which will transport RNG generated from the landfill to Aspire Energy’s
pipeline system, displacing conventionally produced natural gas. In conjunction with this expansion, Aspire Energy also upgraded
an existing compressor station and installed two new metering and regulation sites. Once flowing, the RNG volume will represent
nearly 10 percent of Aspire Energy’s gas gathering volumes.
Bioenergy Devco
In June 2020, our Delmarva natural gas operations and Bioenergy DevCo (“BDC”), a developer of anaerobic digestion facilities
that create renewable energy and healthy soil products from organic material, entered into an agreement related to a project to
extract RNG from poultry production waste. BDC and our affiliates are collaborating on this project in addition to several other
project sites where organic waste can be converted into a carbon-negative energy source.
Marlin Gas Services will transport the RNG created from the organic waste from the BDC facility to an Eastern Shore
interconnection, where the sustainable fuel will be introduced into our transmission system and ultimately distributed to our
natural gas customers.
CleanBay Project
In July 2020, our Delmarva natural gas operations and CleanBay Renewables Inc. ("CleanBay") announced a new partnership to
bring RNG to our operations. As part of this partnership, we will transport the RNG produced at CleanBay's planned Westover,
Maryland bio-refinery, to our natural gas infrastructure in the Delmarva Peninsula region. Eastern Shore and Marlin Gas Services,
will transport the RNG from CleanBay to our Delmarva natural gas distribution system where it is ultimately delivered to the
Delmarva natural gas distribution end use customers.
Chesapeake Utilities Corporation 2021 Form 10-K Page 34
At the present time, we expect to generate adjusted gross margin of $1.0 million in 2022 and beyond from renewable natural gas
transportation. As we continue to finalize contract terms associated with some of these projects, additional information will be
provided regarding incremental margin at a future time.
Acquisitions
Diversified Energy
On December 15, 2021, Sharp Energy acquired the propane operating assets of Diversified Energy Company for approximately
$37.5 million net of cash acquired. There are multiple strategic benefits to this acquisition including it: (i) expands the Company's
propane territory into North Carolina and South Carolina while also expanding our existing footprint in Pennsylvania and Virginia,
and (ii) includes an established customer base with opportunities for future growth. Through this acquisition, the Company adds
approximately 19,000 residential, commercial and agricultural customers, along with distribution of approximately 10.0 million
gallons of propane annually. For the year ended December 31, 2021, Diversified Energy contributed $0.6 million in adjusted
gross margin and is expected to generate $11.3 million of additional adjusted gross margin in 2022 and $12.0 million in 2023.
Elkton Gas
In July 2020, we closed on the acquisition of Elkton Gas, which provides natural gas distribution service to approximately 7,000
residential and commercial customers within a franchised area of Cecil County, Maryland. The purchase price was approximately
$15.6 million, which included $0.6 million of working capital. Elkton Gas’ territory is contiguous to our franchised service
territory in Cecil County, Maryland. We generated $2.2 million in additional adjusted gross margin from Elkton Gas for the year
ended December 31, 2021 and estimates that this acquisition will generate adjusted gross margin of approximately $3.7 million
in 2022 and growing each year thereafter, as the distribution system serving Cecil County further expands to meet demand.
Western Natural Gas
In October 2020, Sharp acquired certain propane operating assets of Western Natural Gas, which provides propane distribution
service throughout Jacksonville, Florida and the surrounding communities, for approximately $6.7 million, net of cash acquired
The Company generated $1.4 million in additional adjusted gross margin from Western Natural Gas in 2021 and estimates that
this acquisition will generate adjusted gross margin of approximately $2.0 million in 2022 with additional margin growth expected
in future years as we further expand our presence.
Escambia Meter Station
In June 2021, Peninsula Pipeline purchased the Escambia Meter Station from Florida Power and Light and entered into a
Transportation Service Agreement with Gulf Power Company to provide up to 530,000 Dts/d of firm service from an interconnect
with FGT to Florida Power & Light’s Crist Lateral pipeline. The Florida Power & Light Crist Lateral provides gas supply to their
natural gas fired power plant owned by Florida Power & Light in Pensacola, Florida. The Company generated $0.6 million in
additional adjusted gross margin in 2021 and estimates that this acquisition will generate adjusted gross margin of approximately
$1.0 million in 2022 and beyond.
Regulatory Initiatives
Florida GRIP
Florida GRIP is a natural gas pipe replacement program approved by the Florida PSC that allows automatic recovery, through
rates, of costs associated with the replacement of mains and services. Since the program's inception in August 2012, the Company
has invested $189.5 million of capital expenditures to replace 348 miles of qualifying distribution mains, including $23.6 million
and $21.0 million of new pipes during 2021 and 2020, respectively. GRIP generated additional gross margin of $1.8 million for
the year ended 2021 compared to 2020. We are currently projecting to complete this program in 2022 and expect to generate
adjusted gross margin of $18.8 million and $19.5 million in 2022 and 2023, respectively. The adjusted gross margin on GRIP
investments will continue until the Company requests the remaining net GRIP investment, and the associated expenses, be
included in its next base rate proceeding.
Chesapeake Utilities Corporation 2021 Form 10-K Page 35
Hurricane Michael
In October 2018, Hurricane Michael passed through FPU's electric distribution operation's service territory in Northwest Florida
and caused widespread and severe damage to FPU's infrastructure resulting in 100 percent of its customers in the Northwest
Florida service territory losing electrical service.
In September 2020, the Florida PSC approved a settlement agreement between FPU and the Office of the Public Counsel
regarding final cost recovery and rates associated with Hurricane Michael. Previously, in late 2019, the Florida PSC approved an
interim rate increase, subject to refund, effective January 1, 2020, associated with the restoration effort following Hurricane
Michael. The Company fully reserved these interim rates, pending a final resolution and settlement of the limited proceeding.
The settlement agreement allowed us to: (a) refund the over-collection of interim rates through the fuel clause; (b) record
regulatory assets for storm costs in the amount of $45.8 million including interest which will be amortized over six years; (c)
recover these storm costs through a surcharge for a total of $7.7 million annually; and (d) collect an annual increase in revenue
of $3.3 million to recover capital costs associated with new plant investments and a regulatory asset for the cost of removal and
unrecovered plant costs. The new base rates and storm surcharge were effective on November 1, 2020. The following table
summarizes the impact of Hurricane Michael regulatory proceeding for the years ended December 31, 2021 and 2020:
(in thousands)
Adjusted Gross Margin
Depreciation
Amortization of regulatory assets
Operating income
Amortization of liability associated with interest expense
Pre-tax income
Income tax expense
Net income
Capital Cost Surcharge Programs
For the Year Ended
December 31,
2021
For the Year Ended
December 31,
2020
$
$
11,492 $
1,218
(8,317)
4,393
1,207
5,600
(1,484)
4,116 $
10,864
1,184
(8,317)
3,731
1,475
5,206
(1,403)
3,803
In December 2019, the FERC approved Eastern Shore’s capital cost surcharge to become effective January 1, 2020. The
surcharge, an approved item in the settlement of Eastern Shore’s last general rate case, allows Eastern Shore to recover capital
costs associated with mandated highway or railroad relocation projects that required the replacement of existing Eastern Shore
facilities. In 2021 there was $0.7 million of adjusted gross margin was added pursuant to the program. Eastern Shore expects to
produce adjusted gross margin of approximately $2.0 million in 2022 and 2023 from relocation projects, which is ultimately
dependent upon the timing of filings and the completion of construction.
Elkton Gas STRIDE Plan
In March 2021, Elkton Gas filed a STRIDE plan with the Maryland PSC. The STRIDE plan proposes to increase the speed of
Elkton Gas' Aldyl-A pipeline replacement program and to recover the costs of the plan in the form of a fixed charge rider through
a proposed 5-year surcharge. Under Elkton Gas’ proposed STRIDE plan, the Aldyl-A pipelines would be replaced by 2023. In
June 2021, we reached a settlement with the Maryland PSC Staff and the Maryland Office of the Peoples Counsel. The STRIDE
plan went into service in September 2021 and is expected to generate $0.3 million of additional adjusted gross margin in 2022
and $0.4 million annually thereafter.
COVID-19 Regulatory Proceeding
In October 2020, the Florida PSC approved a joint petition of our natural gas and electric distribution utilities in Florida to
establish a regulatory asset to record incremental expenses incurred due to COVID-19. The regulatory asset will allow us to seek
recovery of these costs in the next base rate proceedings. In November 2020, the Office of Public Counsel filed a protest to the
Chesapeake Utilities Corporation 2021 Form 10-K Page 36
order approving the establishment of this regulatory asset treatment. The Company’s Florida regulated business units reached a
settlement with Office of Public Counsel in June 2021. The settlement allowed the business units to establish a regulatory asset
of $2.1 million. This amount includes COVID-19 related incremental expenses for bad debt write-offs, personnel protective
equipment, cleaning and business information services for remote work. Our Florida regulated business units will amortize the
amount over two years beginning January 1, 2022 and recover the regulatory asset through the Purchased Gas Adjustment and
Swing Service mechanisms for the natural gas business units and through the Fuel Purchased Power Cost Recovery clause for
the electric division. This results in annual additional adjusted gross margin of $1.0 million that will be offset by a corresponding
amortization of regulatory asset expense for both 2022 and 2023.
Other Major Factors Influencing Adjusted Gross Margin
Weather and Consumption
Weather conditions accounted for increased adjusted gross margin of $5.5 million in 2021 compared to 2020. Assuming normal
temperatures, as detailed below, adjusted gross margin would have been higher by $2.2 million. The following table summarizes
heating degree day ("HDD") and cooling degree day (“CDD”) variances from the 10-year average HDD/CDD ("Normal") for the
years ended December 31, 2021 compared to 2020 and December 31, 2020 compared to 2019.
HDD and CDD Information
Delmarva
Actual HDD
10-Year Average HDD ("Normal")
Variance from Normal
Florida (1)
Actual HDD
10-Year Average HDD ("Normal")
Variance from Normal
Ohio
Actual HDD
10-Year Average HDD ("Normal")
Variance from Normal
Florida (1)
Actual CDD
10-Year Average CDD ("Normal")
Variance from Normal
For the Years Ended December 31,
2021
2020
Variance
2020
2019
Variance
3,849
4,182
(333)
3,716
4,294
(578)
133
(112)
3,716
4,294
(578)
4,089
4,379
(290)
(373)
(85)
829
839
(10)
745
933
(188)
84
(94)
745
933
(188)
740
967
(227)
5,138
5,621
(483)
5,218
5,701
(483)
(80)
(80)
5,218
5,701
(483)
5,500
5,983
(483)
2,687
2,952
(265)
3,078
2,931
147
(391)
21
3,078
2,931
147
3,194
2,889
305
5
(34)
(282)
(282)
(116)
42
(1) Prior year amounts have been revised to conform to the current period presentation.
Natural Gas Distribution Growth
Customer growth for our natural gas distribution operations, as a result of the addition of new customers and the conversion of
customers from alternative fuel sources to natural gas service, generated $3.1 million of additional adjusted gross margin in 2021.
The average number of residential customers served on the Delmarva Peninsula and Florida increased by approximately 4.5
percent and 4.7 percent, respectively, during 2021. On the Delmarva Peninsula, a larger percentage of the adjusted gross margin
Chesapeake Utilities Corporation 2021 Form 10-K Page 37
growth was generated from residential growth given the expansion of gas into new housing communities and conversions to
natural gas as our distribution infrastructure continues to build out. In Florida, as new communities continue to build out due to
population growth and infrastructure is added to support the growth, there is increased load from both residential customers as
well as new commercial and industrial customers. The details are provided in the following table:
(in thousands)
Customer growth:
Residential
Commercial and industrial
Total customer growth
REGULATED ENERGY
For the Year Ended December
(in thousands)
Revenue
Natural gas and electric costs
Adjusted gross margin (1)
Operations & maintenance
Gain from a settlement
Depreciation & amortization
Other taxes
Other operating expenses
Operating Income
Adjusted Gross Margin increase
For the Year Ended December 31, 2021
Delmarva
Peninsula
Florida
$
$
1,468 $
278
1,746 $
1,010
328
1,338
2021
2020
Increase
(decrease)
2020
2019
Increase
(decrease)
$
383,920 $
100,737
283,183
108,300
—
48,748
20,071
177,119
352,746 $
91,994
260,752
104,379
(130)
46,079
18,300
168,628
31,174 $ 352,746 $ 343,006 $
102,803
91,994
8,743
240,203
260,752
22,431
102,099
104,379
3,921
(130)
(130)
130
35,227
46,079
2,669
16,423
18,300
1,771
153,619
168,628
8,491
9,740
(10,809)
20,549
2,280
—
10,852
1,877
15,009
$
106,064 $
92,124 $
13,940 $
92,124 $
86,584 $
5,540
1) Adjusted Gross Margin is a non-GAAP measure utilized by Management to review business unit performance. For a more detailed discussion on the differences
between Gross Margin (GAAP) and Adjusted Gross Margin, see the Reconciliation of GAAP to Non-GAAP Measures presented above.
2021 compared to 2020
Operating income for the Regulated Energy segment for 2021 was $106.1 million, an increase of $13.9 million, or 15.1 percent,
compared to 2020. Higher operating income reflects continued pipeline expansions by Eastern Shore and Peninsula Pipeline,
organic growth in the natural gas distribution businesses, increased consumption from a return toward pre-pandemic consumption
levels and operating results from 2020 and 2021 acquisitions. We recorded higher depreciation, amortization and property taxes
of $4.3 million related to recent capital investments and net operating expenses of $4.2 million. The increase was associated
primarily with an increase in outside services, employee related costs and increased spending with the 2020 and 2021 acquisitions.
In addition to these growth drivers, the increase in other operating expenses was also attributable to operations returning towards
pre-pandemic conditions. Partially offsetting the increase was the establishment of regulatory assets for COVID-19 expenses
approved by the various state PSCs of approximately $2.4 million.
Chesapeake Utilities Corporation 2021 Form 10-K Page 38
Items contributing to the year-over-year adjusted gross margin increase are listed in the following table:
(in thousands)
Eastern Shore and Peninsula Pipeline service expansions
Natural gas distribution customer growth (excluding service expansions)
Increased customer consumption - primarily due to return to pre-pandemic consumption
Contributions from 2020 and 2021 acquisitions
Florida GRIP
Increased customer consumption - primarily weather related
Improved results from electric operations
Eastern Shore capital relocation and non-service expansion projects
Sandpiper infrastructure rider associated with conversions
Other
$
7,168
3,084
3,027
2,787
1,817
1,159
1,015
676
665
1,033
Year-over-year increase in adjusted gross margin
$
22,431
The following narrative discussion provides further detail and analysis of the significant variances in adjusted gross margin
detailed above.
Eastern Shore and Peninsula Pipeline Service Expansions
We generated increased earnings of $5.1 million from Peninsula Pipeline's Western Palm Beach County and Callahan projects
and $2.1 million from Eastern Shore's Del-Mar Energy Pathway project.
Natural Gas Distribution Customer Growth
Organic growth within our natural gas distribution businesses improved operating results compared to the full year 2020.
Residential customer growth was 4.5 percent on the Delmarva Peninsula and 4.7 percent in Florida compared to the prior year.
On the Delmarva Peninsula, a larger percentage of our results was generated from residential growth given the expansion of gas
into new communities and conversions, while in Florida, as gas heating is not a significant portion of residential use, a greater
portion occurred in the commercial and industrial sectors.
Consumption Increase – Return Towards Pre-pandemic Conditions
Increased customer consumption, which reflects the ongoing return toward pre-pandemic conditions in our service territories as
a result of the expiration of restrictions imposed to slow down the spread of COVID-19 increased adjusted gross margin by $3.0
million.
Contribution from Acquisitions
The acquisition of Elkton Gas in July 2020 and the Escambia meter station in June 2021 increased adjusted gross margin by
$2.8 million.
Florida GRIP
Continued investment in the Florida GRIP generated additional adjusted gross margin of $1.8 million.
Increased Customer Consumption - Weather Related
Adjusted gross margin increased by $1.2 million due to colder weather and higher other consumption on the Delmarva Peninsula
and in Florida in 2021 compared to 2020. The weather on the Delmarva Peninsula was 4 percent cooler in 2021 compared to
2020.
Improved Results from Electric Operations
Our electric operations generated additional adjusted gross margin of $1.0 million due to increased consumption and growth.
Eastern Shore Capital Relocation and Non-service Expansion Projects
Chesapeake Utilities Corporation 2021 Form 10-K Page 39
We generated additional adjusted gross margin of $0.7 million from Eastern Shore's surcharge on capital spent on several
governmental-mandated relocation and non-service expansion projects.
Sandpiper Energy Infrastructure Rider Associated with Conversions
Conversion of Sandpiper Energy's propane customers to natural gas customers generated additional adjusted gross margin of $0.7
million.
The major components of the increase in other operating expenses are as follows:
(in thousands)
Depreciation, amortization and property tax costs due to new capital investments
Outside services due to growth and a return toward pre-pandemic conditions
Payroll, benefits and other employee-related expenses
Operating expenses from the Elkton Gas acquisition
Regulatory deferral of COVID-19 expenses per PSCs orders
Other variances
Period-over-period increase in other operating expenses
$
$
4,323
3,102
1,489
1,370
(2,377)
584
8,491
2020 compared to 2019
The results for the Regulated Energy segment for the year ended December 31, 2020 compared to 2019 are described in Item 7,
Management's Discussion and Analysis of Financial Condition and Results of Operations of our Annual Report on Form 10-K
for the year ended December 31, 2020, which is incorporated herein by reference.
UNREGULATED ENERGY
For the Year Ended December 31,
(in thousands)
Revenue
Propane and natural gas costs
Adjusted gross margin (1)
Operations & maintenance
Depreciation & amortization
Other taxes
Other operating expenses
Operating Income
2021
2020
Increase
(decrease)
2020
2019
Increase
(decrease)
$ 206,869 $ 152,526 $
62,780
89,746
53,839
11,988
3,255
69,082
20,664 $
106,900
99,969
57,950
13,869
3,768
75,587
24,382 $
$
54,343 $ 152,526
44,120
62,780
10,223
89,746
4,111
53,839
1,881
11,988
513
3,255
6,505
69,082
3,718 $
20,664
$ 154,150 $
68,884
85,266
52,028
10,130
3,170
65,328
19,938 $
$
(1,624)
(6,104)
4,480
1,811
1,858
85
3,754
726
1) Adjusted Gross Margin is a non-GAAP measure utilized by Management to review business unit performance. For a more detailed discussion on the differences
between Gross Margin (GAAP) and Adjusted Gross Margin, see the Reconciliation of GAAP to Non-GAAP Measures presented above.
2021 Compared to 2020
Operating income for the Unregulated Energy segment for 2021 was $24.4 million, an increase of $3.7 million compared to 2020.
The higher operating income is a result of weather that was colder than 2020, higher retail propane margins per gallon and service
fees, incremental adjusted gross margin from the propane acquisitions completed in 2020 and 2021, increased demand for Marlin
Gas Services' CNG transportation services and increased customer consumption along with higher rates for Aspire Energy. These
adjusted gross margin increases were partially offset by higher depreciation, amortization and property taxes related to recent
capital investments and acquisitions, a return toward pre-pandemic conditions and a general increase in operating expenses to
support growth in the business.
Chesapeake Utilities Corporation 2021 Form 10-K Page 40
Adjusted Gross Margin
Items contributing to the year-over-year increase in adjusted gross margin are listed in the following table:
(in thousands)
Propane Operations
Increased customer consumption - primarily weather related
Increased retail propane margins per gallon and service fees
Acquisitions of Western Natural Gas and Diversified Energy (completed October 2020 and
December 2021)
Increased wholesale propane margins per gallon
Marlin Gas Services
Increased demand for CNG services
Aspire Energy
Increased customer consumption - primarily weather related
Higher overall rates inclusive of natural gas liquid processing
Other variances
Year-over-year increase in adjusted gross margin
$
$
3,603
3,250
1,986
388
334
757
325
(420)
10,223
The following narrative discussion provides further detail and analysis of the significant items in the foregoing table.
Propane Operations
•
•
Increased Customer Consumption Primarily Weather Related - Adjusted gross margin increased by $3.6 million for the
Mid-Atlantic propane operations as weather on the Delmarva Peninsula was 4 percent colder in 2021 compared to 2020.
Increased Retail Propane Margins Per Gallon and Service Fees - Adjusted gross margin increased by $3.2 million, due
to lower propane inventory costs and favorable market conditions as well as resuming the assessment of our customary
service fees. These market conditions, which include competition with other propane suppliers, as well as the availability
and price of alternative energy sources, may fluctuate based on changes in demand, supply and other energy commodity
prices.
• Acquisitions of Western Natural Gas and Diversified Energy - We generated adjusted gross margin of $1.4 million from
Western Natural Gas which was acquired by Sharp in October 2020 and $0.6 million from Diversified Energy which
was acquired by Sharp in December 2021.
•
Increased Wholesale Propane Margins per Gallon - Adjusted gross margin increased by $0.4 million during 2021 over
the same period in 2020, due to lower propane inventory costs and favorable market conditions. These conditions tend
to fluctuate based on changes in demand, supply and other energy commodity prices.
Marlin Gas Services
•
Increased demand for Marlin Gas Services’ CNG hold services improved operating results compared to 2020.
Aspire Energy
•
•
Increased Customer Consumption Primarily Weather Related - Adjusted gross margin increased by $0.8 million due to
higher consumption related to weather as compared to the prior year.
Improved Performance From Natural Gas Liquid Processing - Adjusted gross margin increased by $0.3 million, from
natural gas liquid processing activities compared to 2020.
Other Operating Expenses
Items contributing to the period-over-period increase in other operating expenses are listed in the following table:
Chesapeake Utilities Corporation 2021 Form 10-K Page 41
(in thousands)
Depreciation, amortization and property tax costs due to new capital investments
Operating expenses from Western Natural Gas and Diversified Energy acquisitions
Increased facilities and maintenance costs
Increased vehicle expenses
Insurance related costs (non-health)
Outside services due to growth and a return toward pre-pandemic conditions
Payroll, benefits and other employee-related expenses due to growth
Other variances
Period-over-period increase in other operating expenses
$
$
1,985
1,130
1,036
417
395
364
311
867
6,505
2020 compared to 2019
The results for the Unregulated Energy segment for the year ended December 31, 2020 compared to 2019 are described in Item
7, Management's Discussion and Analysis of Financial Condition and Results of Operations of our Annual Report on Form 10-
K for the year ended December 31, 2020, which is incorporated by reference.
Divestiture of PESCO
During the fourth quarter of 2019, we sold PESCO's assets and contracts and accordingly have exited the natural gas marketing
business. This was done in an effort to enable us to focus on the strategies that support our core energy delivery business. As a
result, we began to report PESCO as discontinued operations during the third quarter of 2019 and excluded PESCO's performance
from continuing operations for all periods presented and classified its assets and liabilities as held for sale, where applicable.
OTHER INCOME (EXPENSE), NET
Other income (expense), net was $1.7 million and $3.2 million for 2021 and 2020, respectively. Other income (expense), net
includes non-operating investment income (expense), interest income, late fees charged to customers, gains or losses from the
sale of assets for our unregulated businesses and pension and other benefits expense. The decrease was primarily due to a higher
level of asset sales in 2020 compared to 2021.
INTEREST CHARGES
2021 Compared to 2020
Interest charges for 2021 decreased by $1.6 million, compared to the same period in 2020. In the fourth quarter of 2020, the
9.08% FPU secured first mortgage bonds were terminated resulting in $1.0 million in interest and fees associated with the early
payoff. Interest expense, which included the expense associated with the bonds decreased by $0.6 million due primarily to lower
levels outstanding under our revolving credit facilities and lower interest rates on short-term borrowings. This decrease was offset
by an increase of $0.5 million primarily due to lower capitalized interest associated with growth projects and $0.3 million of an
amortization credit/reduction in interest expense associated with a regulatory liability that was established in connection with the
Hurricane Michael regulatory proceeding settlement.
INCOME TAXES
2021 Compared to 2020
Income tax expense from continuing operations was $29.2 million for 2021 compared to $23.5 million for 2020. Our effective
income tax rates were 25.9 percent and 25.0 percent for the year ended December 31, 2021 and 2020, respectively. During the
years ended December 31, 2021 and 2020 we implemented certain provisions of the CARES Act that allowed us to carryback net
Chesapeake Utilities Corporation 2021 Form 10-K Page 42
operating losses into prior year periods where the federal income tax rate was higher. As a result, we recognized a $0.9 million
reduction in tax expense for the twelve months ended December 31, 2021 and a $1.8 million reduction for the twelve months
ended December 31, 2020. Excluding this impact of the CARES Act, our effective` tax rates for the years ended December 31,
2021 and 2020 were 26.8 percent and 26.9 percent, respectively.
LIQUIDITY AND CAPITAL RESOURCES
Our capital requirements reflect the capital-intensive and seasonal nature of our business and are principally attributable to
investment in new plant and equipment, retirement of outstanding debt and seasonal variability in working capital. We rely on
cash generated from operations, short-term borrowings, and other sources to meet normal working capital requirements and to
temporarily finance capital expenditures. We may also issue long-term debt and equity to fund capital expenditures and to
maintain our capital structure within our target capital structure range. We maintain an effective shelf registration statement with
the SEC for the issuance of shares of common stock under various types of equity offerings, including shares of common stock
under our ATM equity program, as well as an effective registration statement with respect to the DRIP. Depending on our capital
needs and subject to market conditions, in addition to other possible debt and equity offerings, we may consider issuing additional
shares under the direct share purchase component of the DRIP and/or under the ATM equity program. Beginning in the third
quarter of 2020, we issued shares of common stock under both the DRIP and the ATM equity program.
Our energy businesses are weather-sensitive and seasonal. We normally generate a large portion of our annual net income and
subsequent increases in our accounts receivable in the first and fourth quarters of each year due to significant volumes of natural
gas, electricity, and propane delivered by our distribution operations, and our natural gas transmission operations to customers
during the peak heating season. In addition, our natural gas and propane inventories, which usually peak in the fall months, are
largely drawn down in the heating season and provide a source of cash as the inventory is used to satisfy winter sales demand.
Capital expenditures for investments in new or acquired plant and equipment are our largest capital requirements. Our capital
expenditures were $227.8 million in 2021.
The following table shows total capital expenditures for the year ended December 31, 2021 by segment and by business line:
(dollars in thousands)
Regulated Energy:
Natural gas distribution
Natural gas transmission
Electric distribution
Total Regulated Energy
Unregulated Energy:
Propane distribution
Energy transmission
Other unregulated energy
Total Unregulated Energy
Other:
Corporate and other businesses
Total Other
Total 2021 Capital Expenditures
For the Year Ended
December 31, 2021
$
$
78,084
55,149
6,500
139,733
46,023
20,101
15,527
81,651
6,425
6,425
227,809
In the table below, we have provided a range of our forecasted capital expenditures for 2022:
Chesapeake Utilities Corporation 2021 Form 10-K Page 43
(dollars in thousands)
Regulated Energy:
Natural gas distribution
Natural gas transmission
Electric distribution
Total Regulated Energy
Unregulated Energy:
Propane distribution
Energy transmission
Other unregulated energy
Total Unregulated Energy
Other:
Corporate and other businesses
Total Other
Total 2022 Forecasted Capital Expenditures
Estimate for Fiscal 2022
High
Low
$
$
87,000
60,000
7,000
154,000
10,000
5,000
4,000
19,000
92,000
67,000
12,000
171,000
14,000
6,000
5,000
25,000
2,000
2,000
175,000
$
4,000
4,000
200,000
$
The 2022 forecast, excluding acquisitions, includes capital expenditures for the following: Pipeline expansions related to the
Eastern Shore Southern expansion and the Florida Beachside Pipeline as well as amounts for the expansion into Somerset County,
Maryland. Furthermore, the 2022 forecast includes continued expenditures under the Florida GRIP, the capital cost surcharge
program and the Elkton Gas STRIDE program as well as further expansion of our natural gas distribution and transmission
systems, information technology systems and other strategic initiatives and investments.
The capital expenditure projection is subject to continuous review and modification. Actual capital requirements may vary from
the above estimates due to a number of factors, including changing economic conditions, capital delays because of COVID-19
that are greater than currently anticipated, customer growth in existing areas, regulation, new growth or acquisition opportunities,
availability of capital and other factors discussed in Item 1A. Risk Factors. Historically, actual capital expenditures have typically
lagged behind the budgeted amounts.
The timing of capital expenditures can vary based on delays in regulatory approvals, securing environmental approvals and other
permits. The regulatory application and approval process has lengthened in the past few years, and we expect this trend to
continue.
Capital Structure
We are committed to maintaining a sound capital structure and strong credit ratings. This commitment, along with adequate and
timely rate relief for our regulated energy operations, is intended to ensure our ability to attract capital from outside sources at a
reasonable cost, which will benefit our customers, creditors, employees and stockholders.
The following tables present our capitalization, excluding and including short-term borrowings, as of December 31, 2021 and
2020 follows:
(in thousands)
Long-term debt, net of current maturities
Stockholders’ equity
Total capitalization, excluding short-term borrowings
December 31, 2021
December 31, 2020
$
549,903
774,130
$ 1,324,033
508,499
42 % $
697,085
58 %
100 % $ 1,205,584
42 %
58 %
100 %
Chesapeake Utilities Corporation 2021 Form 10-K Page 44
(in thousands)
Short-term debt
Long-term debt, including current maturities
Stockholders’ equity
Total capitalization, including short-term borrowings
December 31, 2021
December 31, 2020
$
221,634
567,866
774,130
$ 1,563,630
175,644
14 % $
522,099
36 %
697,085
50 %
100 % $ 1,394,828
13 %
37 %
50 %
100 %
Our target ratio of equity to total capitalization, including short-term borrowings, is between 50 and 60 percent. Our equity to
total capitalization ratio, including short-term borrowings, was approximately 50 percent as of December 31, 2021. We seek to
align permanent financing with the in-service dates of capital projects. We may utilize more temporary short-term debt when the
financing cost is attractive as a bridge to the permanent long-term financing or if the equity markets are volatile.
In 2021, we issued just over 0.1 million shares at an average price per share of $125.71 and received net proceeds of $15.2 million
under the DRIP. In the third and fourth quarters of 2020, we issued 1.0 million shares of common stock through our DRIP and
the ATM programs and received net proceeds of approximately $83.0 million which were added to the general funds and then
used to pay down short-term borrowing. See Note 16, Stockholders’ Equity, in the consolidated financial statements for additional
information on commissions and fees paid in connection with these issuances.
Uncollateralized Senior Notes
All of our Senior Notes require periodic principal and interest payments as specified in each note. They also contain various
restrictions. The most stringent restrictions state that we must maintain equity of at least 40 percent of total capitalization
(including short-term borrowings), and the fixed charge coverage ratio must be at least 1.2 times. The most recent Senior Notes
issued since September 2013 also contain a restriction that we must maintain an aggregate net book value in our regulated business
assets of at least 50 percent of our consolidated total assets. Failure to comply with those covenants could result in accelerated
due dates and/or termination of the Senior Note agreements.
Certain Uncollateralized Senior Notes contain a “restricted payments” covenant as defined in the respective note agreements. The
most restrictive covenants of this type are included within the 5.93 percent Senior Note, due October 31, 2023. The covenant
provides that we cannot pay or declare any dividends or make any other restricted payments in excess of the sum of $10.0 million,
plus our consolidated net income accrued on and after January 1, 2003. As of December 31, 2021, the cumulative consolidated
net income base was $664.5 million, offset by restricted payments of $289.4 million, leaving $375.1 million of cumulative net
income free of restrictions.
Shelf Agreements
We have entered into Shelf Agreements with Prudential and MetLife, whom are under no obligation to purchase any unsecured
debt. The following table summarizes our Shelf Agreements at December 31, 2021:
Shelf Agreement
(in thousands)
Prudential Shelf Agreement (1)
MetLife Shelf Agreement (2)
Total
Total
Borrowing
Capacity
Less: Amount
of Debt
Issued
Less:
Unfunded
Commitments
Remaining
Borrowing
Capacity
$
$
370,000 $
150,000
520,000 $
(220,000)
—
(220,000) $
— $
(50,000)
(50,000) $
150,000
100,000
250,000
(1) The Prudential and MetLife Shelf Agreements expire in April 2023 and May 2023, respectively.
(2) Unfunded commitments of $50 million reflects Senior Notes expected to be issued on or before March 15, 2022.
The Senior Notes, Shelf Agreements and Shelf Notes set forth certain business covenants to which we are subject when any note
is outstanding, including covenants that limit or restrict our ability, and the ability of our subsidiaries, to incur indebtedness, or
place or permit liens and encumbrances on any of our property or the property of our subsidiaries.
Chesapeake Utilities Corporation 2021 Form 10-K Page 45
Short-Term Borrowings
We are authorized by our Board of Directors to borrow up to $400.0 million of short-term debt, as required. At December 31,
2021 and 2020, we had $221.6 million and $175.6 million, respectively, of short-term borrowings outstanding at a weighted
average interest rate of 0.83 percent and 1.28 percent, respectively.
In August 2021, we amended and restated our Revolver into a multi-tranche facility totaling $400.0 million with multiple
participating lenders. The two tranches of the facility consist of a $200.0 million 364-day short-term debt tranche and a $200.0
million five-year tranche, both of which have three one-year extension options, which can be authorized by our Chief Financial
Officer. We are eligible to establish the repayment term for individual borrowings under the five year tranche of the facility and
to the extent that an individual loan under the revolver exceeded 12 months, the outstanding balance would be classified as a
component of long-term debt.
The availability of funds under the Revolver is subject to conditions specified in the credit agreement, all of which we currently
satisfy. These conditions include our compliance with financial covenants and the continued accuracy of representations and
warranties contained in these agreements. We are required by the financial covenants in the Revolver to maintain, at the end of
each fiscal year, a funded indebtedness ratio of no greater than 65 percent. As of December 31, 2021, we are in compliance with
this covenant.
The 364-day tranche of the Revolver expires in August 2022 and the five-year tranche expires in August 2026. Both tranches are
available to provide funds for our short-term cash needs to meet seasonal working capital requirements and to temporarily fund
portions of our capital expenditures. Borrowings under both tranches of the Revolver are subject to a pricing grid, including the
commitment fee and the interest rate charged. Our pricing is adjusted each quarter based upon a total indebtedness to total
capitalization ratio. As of December 31, 2021, the pricing under the 364-day tranche of the Revolver does not include an unused
commitment fee and maintains an interest rate of 0.70 percent over LIBOR. As of December 31, 2021, the pricing under the five-
year tranche of the Revolver included an unused commitment fee of 0.09 percent and an interest rate of 0.95 percent over LIBOR.
Our total available credit under the Revolver at December 31, 2021 was $173.1 million. As of December 31, 2021, we had issued
$5.3 million in letters of credit to various counterparties under the syndicated Revolver. These letters of credit are not included in
the outstanding short-term borrowings and we do not anticipate they will be drawn upon by the counterparties. The letters of
credit reduce the available borrowings under our syndicated Revolver.
In the fourth quarter of 2020, we entered into two $30.0 million interest rate swaps with a total notional amount of $60.0 million
through December 2021 with pricing of 0.20 percent and 0.205 percent for the period associated with our outstanding borrowing
under the Revolver. In February 2021, we entered into an additional interest rate swap with a notional amount of $40.0 million
through December 2021 with pricing of 0.17 percent. As of December 31, 2021 all of our interests rate swaps had expired and
we had not entered into any new swaps.
Key statistics regarding our unsecured short-term credit facilities (our Revolver and previous bilateral lines of credit and revolving
credit facility) for the years ended December 31, 2021, 2020 and 2019 are as follows:
(in thousands)
Average borrowings during the year
Weighted average interest rate for the year
Maximum month-end borrowings
2021
182,305
$
$
2020
230,526
$
2019
257,587
1.03 %
1.50 %
3.11 %
$
226,097
$
284,914
$
302,379
Chesapeake Utilities Corporation 2021 Form 10-K Page 46
Cash Flows
The following table provides a summary of our operating, investing and financing cash flows for the years ended December 31,
2021, 2020 and 2019:
(in thousands)
Net cash provided by (used in):
Operating activities
Investing activities
Financing activities
Net (decrease) increase in cash and cash equivalents
Cash and cash equivalents—beginning of period
Cash and cash equivalents—end of period
Cash Flows Provided by Operating Activities
For the Year Ended December 31,
2019
2020
2021
$
$
150,504 $
(223,023)
73,996
1,477
3,499
4,976 $
158,916 $
(181,631)
19,229
(3,486)
6,985
3,499 $
102,964
(186,587)
84,519
896
6,089
6,985
Changes in our cash flows from operating activities are attributable primarily to changes in net income, adjusted for non-cash
items, such as depreciation and changes in deferred income taxes, and changes in working capital. Working capital requirements
are determined by a variety of factors, including weather, the prices of natural gas, electricity and propane, the timing of customer
collections, payments for purchases of natural gas, electricity and propane, and deferred fuel cost recoveries.
We normally generate a large portion of our annual net income and related increases in our accounts receivable in the first and
fourth quarters of each year due to significant volumes of natural gas and propane delivered to customers during the peak heating
season by our natural gas and propane operations and our natural gas supply, gathering and processing operation. In addition, our
natural gas and propane inventories, which usually peak in the fall months, are largely drawn down in the heating season and
provide a source of cash as the inventory is used to satisfy winter sales demand.
During 2021, net cash provided by operating activities was $150.5 million. Operating cash flows were primarily impacted by the
following:
• Net income, adjusted for non-cash adjustments, provided a $162.3 million source of cash;
• An increased level of deferred taxes associated with incremental tax depreciation from growth investments resulted in a
source of cash of $26.7 million;
• Changes in net regulatory assets and liabilities due primarily to the change in fuel costs collected through the various
cost recovery mechanisms generated an $18.5 million use of cash;
• Working capital changes, impacted primarily by propane inventory purchases and hedging activities, resulted in a $15.4
million use of cash; and
• An increase in income tax receivables reduced cash inflows by $4.6 million.
Cash Flows Used in Investing Activities
Net cash used in investing activities totaled $223.0 million during the year ended December 31, 2021. Key investing activities
contributing to the cash flow change included:
• Cash used to pay for capital expenditures was $186.9 million for 2021; and
• Net cash of $36.4 million was used to acquire certain propane operating assets of Diversified Energy in 2021.
Cash Flows Provided by Financing Activities
Net cash provided by financing activities totaled $74.0 million for the year ended December 31, 2021. Net cash provided by
financing activities:
• Net increase in borrowings under lines of credit of $46.6 million to support working capital needs and short-term capital
spending;
Chesapeake Utilities Corporation 2021 Form 10-K Page 47
• Net increase in long-term debt borrowings resulted in a source of cash of $45.7 million to permanently finance
investment in growth initiatives;
Source of cash of $15.9 million from issuance of stock under the DRIP; and
•
• A use of cash of $31.5 million for dividend payments in 2021.
CONTRACTUAL OBLIGATIONS
We have the following contractual obligations and other commercial commitments as of December 31, 2021:
Contractual Obligations
(in thousands)
Long-term debt (1)
Operating leases (2)
Purchase obligations (3)
Transmission capacity
Storage capacity
Commodities
Electric supply
Unfunded benefits (4)
Funded benefits (5)
Total Contractual Obligations
2022
2023-2024
Payments Due by Period
2025-2026
After 2026
Total
$
17,962 $
2,019
39,988 $
3,574
60,078 $
2,226
450,750 $
3,668
568,778
11,487
35,368
2,741
45,066
6,382
315
2,104
111,957 $
68,183
1,391
—
12,838
611
3,607
130,192 $
56,566
612
—
12,936
583
3,607
136,608 $
147,899
383
—
25,921
1,265
3,052
308,016
5,127
45,066
58,077
2,774
12,370
632,938 $ 1,011,695
$
(1) This represents principal payments on long-term debt. See Item 8, Financial Statements and Supplementary Data, Note 13, Long-Term Debt, for additional
information. The expected interest payments on long-term debt are $18.8 million, $36.0 million, $32.8 million and $90.2 million, respectively, for the periods
indicated above. Expected interest payments for all periods total $177.8 million.
(2) See Item 8, Financial Statements and Supplementary Data, Note 15, Leases, for additional information.
(3) See Item 8, Financial Statements and Supplementary Data, Note 21, Other Commitments and Contingencies, for additional information.
(4) These amounts associated with our unfunded post-employment and post-retirement benefit plans are based on expected payments to current retirees and assume
a retirement age of 62 for currently active employees. There are many factors that would cause actual payments to differ from these amounts, including early
retirement, future health care costs that differ from past experience and discount rates implicit in calculations. See Item 8, Financial Statements and Supplementary
Data, Note 17, Employee Benefit Plans, for additional information on the plans.
(5) We have recorded long-term liabilities of $8.3 million at December 31, 2021 for the FPU qualified, defined benefit pension plan. The assets funding this plan
is in a separate trust and is not considered assets of ours or included in our balance sheets. The Contractual Obligations table above includes $0.3 million, reflecting
the payments we expect to make to the trust funds in 2022. Additional contributions may be required in future years based on the actual return earned by the plan
assets and other actuarial assumptions, such as the discount rate and long-term expected rate of return on plan assets. See Item 8, Financial Statements and
Supplementary Data, Note 17, Employee Benefit Plans, for further information on the plans. Additionally, the Contractual Obligations table above includes
deferred compensation obligations totaling $12.1 million, funded with Rabbi Trust assets in the same amount. The Rabbi Trust assets are recorded under
Investments on the consolidated balance sheets. We assume a retirement age of 65 for purposes of distribution from this trust.
OFF-BALANCE SHEET ARRANGEMENTS
Our Board of Directors has authorized us to issue corporate guarantees securing obligations of our subsidiaries and to obtain
letters of credit securing our subsidiaries' obligations. The maximum authorized liability under such guarantees and letters of
credit as of December 31, 2021 was $20.0 million. The aggregate amount guaranteed at December 31, 2021 was $13.1 million,
with the guarantees expiring on various dates through December 1, 2022.
As of December 31, 2021, we have issued letters of credit totaling approximately $5.3 million related to the electric transmission
services for FPU's electric division, the firm transportation service agreement between TETLP and our Delaware and Maryland
divisions, the capacity agreement between NEXUS and Aspire, and our current and previous primary insurance carriers. These
letters of credit have various expiration dates through October 25, 2022. There have been no draws on these letters of credit as of
December 31, 2021. We do not anticipate that the counterparties will draw upon these letters of credit, and we expect that they
will be renewed to the extent necessary in the future. Additional information is presented in Item 8, Financial Statements and
Supplementary Data, Note 21, Other Commitments and Contingencies in the consolidated financial statements.
Chesapeake Utilities Corporation 2021 Form 10-K Page 48
CRITICAL ACCOUNTING ESTIMATES
We prepare our financial statements in accordance with GAAP. Application of these accounting principles requires the use of
estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosures
of contingencies during the reporting period. We base our estimates on historical experience and on various assumptions that are
believed to be reasonable under the circumstances, the results of which form the basis for making judgments about the carrying
value of assets and liabilities that are not readily apparent from other sources. Since a significant portion of our businesses are
regulated and the accounting methods used by these businesses must comply with the requirements of the regulatory bodies, the
choices available are limited by these regulatory requirements. In the normal course of business, estimated amounts are
subsequently adjusted to actual results that may differ from the estimates.
Regulatory Assets and Liabilities
As a result of the ratemaking process, we record certain assets and liabilities in accordance with ASC Topic 980, Regulated
Operations, and consequently, the accounting principles applied by our regulated energy businesses differ in certain respects from
those applied by the unregulated businesses. Amounts are deferred as regulatory assets and liabilities when there is a probable
expectation that they will be recovered in future revenues or refunded to customers as a result of the regulatory process. This is
more fully described in Item 8, Financial Statements and Supplementary Data, Note 2, Summary of Significant Accounting
Policies, in the consolidated financial statements. If we were required to terminate the application of ASC Topic 980, we would
be required to recognize all such deferred amounts as a charge or a credit to earnings, net of applicable income taxes. Such an
adjustment could have a material effect on our results of operations.
Valuation of Environmental Liabilities and Related Regulatory Assets
As more fully described in Item 8, Financial Statements and Supplementary Data, Note 20, Environmental Commitments and
Contingencies, in the consolidated financial statements, we are currently participating in the investigation, assessment or
remediation of former MGP sites for which we have sought or will seek regulatory approval to recover through rates the estimated
costs of remediation and related activities. Amounts have been recorded as environmental liabilities based on estimates of future
costs to remediate these sites, which are provided by independent consultants.
Financial Instruments
We utilize financial instruments to mitigate commodity price risk associated with fluctuations of natural gas, electricity and
propane and to mitigate interest rate risk. We continually monitor the use of these instruments to ensure compliance with our risk
management policies and account for them in accordance with GAAP, such that every derivative instrument is recorded as either
an asset or a liability measured at its fair value. It also requires that changes in the derivatives' fair value are recognized in the
current period earnings unless specific hedge accounting criteria are met. If these instruments do not meet the definition of
derivatives or are considered “normal purchases and normal sales,” they are accounted for on an accrual basis of accounting.
Additionally, GAAP also requires us to classify the derivative assets and liabilities based on the lowest level of input that is
significant to the fair value measurement. Our assessment of the significance of a particular input to the fair value measurement
requires judgment and may affect the fair value of the assets and liabilities and their placement within the fair value hierarchy.
We determined that certain propane put options, call options, swap agreements and interest rate swap agreements met the specific
hedge accounting criteria. We also determined that most of our contracts for the purchase or sale of natural gas, electricity and
propane either: (i) did not meet the definition of derivatives because they did not have a minimum purchase/sell requirement, or
(ii) were considered “normal purchases and normal sales” because the contracts provided for the purchase or sale of natural gas,
electricity or propane to be delivered in quantities that we expect to use or sell over a reasonable period of time in the normal
course of business. Accordingly, these contracts were accounted for on an accrual basis of accounting.
Additional information about our derivative instruments is disclosed in Item 8, Financial Statements and Supplementary Data,
Note 8, Derivative Instruments, in the consolidated financial statements.
Chesapeake Utilities Corporation 2021 Form 10-K Page 49
Operating Revenues
Revenues for our natural gas and electric distribution operations are based on rates approved by the PSC of each state in which
we operate. Customers’ base rates may not be changed without formal approval by these PSCs. However, the PSCs authorized
our regulated operations to negotiate rates, based on approved methodologies, with customers that have competitive alternatives.
Eastern Shore’s revenues are based on rates approved by the FERC. The FERC has also authorized Eastern Shore to negotiate
rates above or below the FERC-approved maximum rates, which customers can elect as an alternative to negotiated rates.
Peninsula Pipeline, our Florida intrastate pipeline subsidiary that is subject to regulation by the Florida PSC, has negotiated firm
transportation service contracts with third-party customers and with certain affiliates.
For regulated deliveries of natural gas, electricity and propane, we read meters and bill customers on monthly cycles that do not
coincide with the accounting periods used for financial reporting purposes. We accrue unbilled revenues for natural gas and
electricity that have been delivered, but not yet billed, at the end of an accounting period to the extent that they do not coincide.
We estimate the amount of the unbilled revenue by jurisdiction and customer class. A similar computation is made to accrue
unbilled revenues for propane customers with meters, such as community gas system customers, whose billing cycles do not
coincide with the accounting periods.
Our Ohio natural gas transmission/supply operation recognizes revenues based on actual volumes of natural gas shipped, using
contractual rates, which are based upon index prices that are published monthly.
Eight Flags records revenues based on the amount of electricity and steam generated and sold to its customers.
Our mobile compressed natural gas operation recognizes revenue for CNG services at the end of each calendar month for services
provided during the month based on agreed upon rates for labor, equipment utilized, costs incurred for natural gas compression,
miles driven, mobilization and demobilization fees.
Each of our natural gas distribution operations in Delaware and Maryland, our bundled natural gas distribution service in Florida
and our electric distribution operation in Florida has a fuel cost recovery mechanism. This mechanism provides a method of
adjusting billing rates to reflect changes in the cost of purchased fuel. The difference between the current cost of fuel purchased
and the cost of fuel recovered in billed rates is deferred and accounted for as either unrecovered fuel cost or amounts payable to
customers. Generally, these deferred amounts are recovered or refunded within one year.
We charge flexible rates to industrial interruptible customers on our natural gas distribution systems to compete with the price of
alternative fuel that they can use. Neither we, nor any of our interruptible customers, are contractually obligated to deliver or
receive natural gas on a firm service basis.
Allowance for Credit Losses
An allowance for expected credit losses is recorded against amounts due to reduce the net receivable balance to the amount we
reasonably expect to collect based upon our collections experience, the condition of the overall economy and our assessment of
our customers’ inability or reluctance to pay. If circumstances change, however, our estimate of the recoverability of accounts
receivable may also change. Circumstances which could affect our estimates include, but are not limited to, customer credit issues,
the level of natural gas, electricity and propane prices, impacts from pandemics and general economic conditions. Accounts are
written off once they are deemed to be uncollectible.
Goodwill and Other Intangible Assets
We test goodwill for impairment at least annually in December. The annual impairment testing for 2021 indicated no impairment
of goodwill. Additional information is presented in Item 8, Financial Statements and Supplementary Data, Note 11, Goodwill
and Other Intangible Assets, in the consolidated financial statements.
Chesapeake Utilities Corporation 2021 Form 10-K Page 50
Other Assets Impairment Evaluations
We periodically evaluate whether events or circumstances have occurred which indicate that long-lived assets may not be
recoverable. When events or circumstances indicate that an impairment is present, we record an impairment loss equal to the
excess of the asset's carrying value over its fair value, if any.
Pension and Other Postretirement Benefits
Pension and other postretirement plan costs and liabilities are determined on an actuarial basis and are affected by numerous
assumptions and estimates including the market value of plan assets, estimates of the expected returns on plan assets, assumed
discount rates, the level of contributions made to the plans, and current demographic and actuarial mortality data. The assumed
discount rates and the expected returns on plan assets are the assumptions that generally have the most significant impact on the
pension costs and liabilities. The assumed discount rates, the assumed health care cost trend rates and the assumed rates of
retirement generally have the most significant impact on our postretirement plan costs and liabilities. Additional information is
presented in Item 8, Financial Statements and Supplementary Data, Note 17, Employee Benefit Plans, in the consolidated
financial statements, including plan asset investment allocation, estimated future benefit payments, general descriptions of the
plans, significant assumptions, the impact of certain changes in assumptions, and significant changes in estimates.
During the fourth quarter of 2021, we formally terminated the Chesapeake Utilities Pension Plan. For 2021, actuarial assumptions
include expected long-term rates of return on plan assets for FPU's pension plan of 6.00 percent and a discount rate of 2.75
percent. The discount rate was determined by management considering high-quality corporate bond rates, such as the Prudential
curve index and the FTSE Index, changes in those rates from the prior year and other pertinent factors, including the expected
lives of the plans and the availability of the lump-sum payment option. A 0.25 percent decrease in the discount rate could decrease
our annual pension and postretirement costs by an immaterial amount, and a 0.25 percent increase could increase our annual
pension and postretirement costs by an immaterial amount.
Actual changes in the fair value of plan assets and the differences between the actual return on plan assets and the expected return
on plan assets could have a material effect on the amount of pension benefit costs that we ultimately recognize. A 0.25 percent
change in the rate of return could change our annual pension cost by approximately $0.1 million and would not have an impact
on the postretirement and Chesapeake Utilities supplemental executive retirement pension plan ("Chesapeake SERP") because
these plans are not funded.
Tax-Related Contingency
We account for uncertainty in income taxes in the consolidated financial statements only if it is more likely than not that an
uncertain tax position is sustainable based on its technical merits. Recognizable tax positions are then measured to determine the
amount of benefit recognized in the consolidated financial statements. We recognize penalties and interest related to unrecognized
tax benefits as a component of other income.
We account for contingencies associated with taxes other than income when the likelihood of a loss is both probable and
quantifiable. In assessing the likelihood of a loss, we do not consider the existence of current inquiries, or the likelihood of future
inquiries, by tax authorities as a factor. Our assessment is based solely on our application of the appropriate statutes and the
likelihood of a loss, assuming the proper inquiries are made by tax authorities.
ITEM 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK.
INTEREST RATE RISK
Long-term debt is subject to potential losses based on changes in interest rates. We evaluate whether to refinance existing debt or
permanently refinance existing short-term borrowings based in part on the fluctuation in interest rates. The fluctuation in interest
rates expose us to potential increased cost we could incur when we issue debt instruments or to provide financing and liquidity
for our business activities. We utilize interest rate swap agreements to mitigate short-term borrowing rate risk. Additional
information about our long-term debt and short-term borrowing is disclosed in Note 13, Long-Term Debt, and Note 14, Short-
Term Borrowings, respectively, in the consolidated financial statements.
Chesapeake Utilities Corporation 2021 Form 10-K Page 51
COMMODITY PRICE RISK
Regulated Energy Segment
We have entered into agreements with various wholesale suppliers to purchase natural gas and electricity for resale to our
customers. Our regulated energy distribution businesses that sell natural gas or electricity to end-use customers have fuel cost
recovery mechanisms authorized by the PSCs that allow us to recover all of the costs prudently incurred in purchasing natural
gas and electricity for our customers. Therefore, our regulated energy distribution operations have limited commodity price risk
exposure.
Unregulated Energy Segment
Our propane operations are exposed to commodity price risk as a result of the competitive nature of retail pricing offered to our
customers. In order to mitigate this risk, we utilize propane storage activities and forward contracts for supply and sales activities.
We can store up to approximately 8.9 million gallons of propane (including leased storage and rail cars) during the winter season
to meet our customers’ peak requirements and to serve metered customers. Decreases in the wholesale price of propane may cause
the value of stored propane to decline, particularly if we utilize fixed price forward contracts for supply. To mitigate the risk of
propane commodity price fluctuations on the inventory valuation, we have adopted a Risk Management Policy that allows our
propane distribution operation to enter into fair value hedges, cash flow hedges or other economic hedges of our inventory.
Aspire Energy is exposed to commodity price risk, primarily during the winter season, to the extent we are not successful in
balancing our natural gas purchases and sales and have to secure natural gas from alternative sources at higher spot prices. In
order to mitigate this risk, we procure firm capacity that meets our estimated volume requirements and we continue to seek out
new producers in order to fulfill our natural gas purchase requirements.
The following table reflects the changes in the fair market value of financial derivatives contracts related to propane purchases
and sales from December 31, 2020 to December 31, 2021:
(in thousands)
Sharp
Balance at
December 31, 2020
Increase
(Decrease) in Fair
Market Value
Less Amounts
Settled
Balance at
December 31, 2021
$
3,182 $
9,802 $
(6,651) $
6,333
There were no changes in the methods of valuations during the year ended December 31, 2021.
The following is a summary of fair market value of financial derivatives as of December 31, 2021, by method of valuation and
by maturity for each fiscal year period.
(in thousands)
Price based on Mont Belvieu - Sharp
2022
2023
2024
Total Fair Value
$
3,574 $
1,983 $
776 $
6,333
WHOLESALE CREDIT RISK
The Risk Management Committee reviews credit risks associated with counterparties to commodity derivative contracts prior to
such contracts being approved.
Additional information about our derivative instruments is disclosed in Item 8, Financial Statements and Supplementary Data,
Note 8, Derivative Instruments, in the consolidated financial statements.
Chesapeake Utilities Corporation 2021 Form 10-K Page 52
INFLATION
Inflation affects the cost of supply, labor, products and services required for operations, maintenance and capital improvements.
To help cope with the effects of inflation on our capital investments and returns, we periodically seek rate increases from
regulatory commissions for our regulated operations and closely monitor the returns of our unregulated energy business
operations. To compensate for fluctuations in propane gas prices, we adjust propane sales prices to the extent allowed by the
market.
Chesapeake Utilities Corporation 2021 Form 10-K Page 53
ITEM 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA.
REPORT OF INDEPENDENT REGISTERED PUBLIC ACCOUNTING FIRM
To the Board of Directors and Stockholders of
Chesapeake Utilities Corporation
Opinions on the Consolidated Financial Statements and Internal Control over Financial Reporting
We have audited the accompanying consolidated balance sheets of Chesapeake Utilities Corporation and Subsidiaries (the
"Company") as of December 31, 2021 and 2020, the related consolidated statements of income, comprehensive income,
stockholders' equity, and cash flows, for each of the years in the three-year period ended December 31, 2021, and the related
notes and financial statement schedule listed in Item 15(a)2 (collectively referred to as the "consolidated financial statements").
We also have audited the Company’s internal control over financial reporting as of December 31, 2021, based on criteria
established in Internal Control - Integrated Framework: (2013) issued by the Committee of Sponsoring Organizations of the
Treadway Commission (“COSO”).
In our opinion, the consolidated financial statements present fairly, in all material respects, the financial position of the Company
as of December 31, 2021 and 2020, and the results of their operations and their cash flows for each of the years in the three-year
period ended December 31, 2021, in conformity with accounting principles generally accepted in the United States of America.
Also in our opinion, the Company maintained, in all material respects, effective internal control over financial reporting as of
December 31, 2021, based on criteria established in Internal Control - Integrated Framework: (2013) issued by COSO.
Basis for Opinion
The Company’s management is responsible for these consolidated financial statements, for maintaining effective internal control
over financial reporting, and for its assessment of the effectiveness of internal control over financial reporting, included in the
accompanying Management's Report on Internal Control Over Financial Reporting. Our responsibility is to express an opinion
on the Company's consolidated financial statements and an opinion on the Company’s internal control over financial reporting
based on our audits. We are a public accounting firm registered with the Public Company Accounting Oversight Board (United
States) ("PCAOB") and are required to be independent with respect to the Company in accordance with the U.S. federal securities
laws and the applicable rules and regulations of the Securities and Exchange Commission and the PCAOB.
We conducted our audits in accordance with the standards of the PCAOB. Those standards require that we plan and perform the
audits to obtain reasonable assurance about whether the consolidated financial statements are free of material misstatement,
whether due to error or fraud, and whether effective internal control over financial reporting was maintained in all material
respects.
Our audits of the consolidated financial statements included performing procedures to assess the risks of material misstatement
of the consolidated financial statements, whether due to error or fraud, and performing procedures that respond to those risks.
Such procedures included examining, on a test basis, evidence regarding the amounts and disclosures in the consolidated financial
statements. Our audits also included evaluating the accounting principles used and significant estimates made by management,
as well as evaluating the overall presentation of the consolidated financial statements. Our audit of internal control over financial
reporting included obtaining an understanding of internal control over financial reporting, assessing the risk that a material
weakness exists, and testing and evaluating the design and operating effectiveness of internal control based on the assessed risk.
Our audits also included performing such other procedures as we considered necessary in the circumstances. We believe that our
audits provide a reasonable basis for our opinions.
Definition and Limitations of Internal Control Over Financial Reporting
A company's internal control over financial reporting is a process designed to provide reasonable assurance regarding the
reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally
accepted accounting principles. A company's internal control over financial reporting includes those policies and procedures that
(1) pertain to the maintenance of records that, in reasonable detail, accurately and fairly reflect the transactions and dispositions
of the assets of the company; (2) provide reasonable assurance that transactions are recorded as necessary to permit preparation
Chesapeake Utilities Corporation 2021 Form 10-K Page 54
of financial statements in accordance with generally accepted accounting principles, and that receipts and expenditures of the
company are being made only in accordance with authorizations of management and directors of the company; and (3) provide
reasonable assurance regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company's
assets that could have a material effect on the financial statements.
Because of its inherent limitations, internal control over financial reporting may not prevent or detect misstatements. Also,
projections of any evaluation of effectiveness to future periods are subject to the risk that controls may become inadequate because
of changes in conditions, or that the degree of compliance with the policies or procedures may deteriorate.
Critical Audit Matter
The critical audit matter communicated below is a matter arising from the current period audit of the consolidated financial
statements that was communicated or required to be communicated to the audit committee and that: (1) relate to accounts or
disclosures that are material to the consolidated financial statements and (2) involved our especially challenging subjective, or
complex judgments. The communication of the critical audit matter does not alter in any way our opinion on the consolidated
financial statements, taken as a whole, and we are not, by communicating the critical audit matter below, providing separate
opinions on the critical audit matter or on the accounts or disclosures to which they relate.
Goodwill Impairment Assessment - Energy Transmission and Supply Services (Aspire Energy), Mid-Atlantic Propane
Operations, Florida Propane Operations and Marlin Gas Services - Unregulated Energy Segment - Refer to Notes 1 and
11 to the consolidated financial statements
Critical Audit Matter Description
As described in Notes 1 and 11 to the consolidated financial statements, the Company has recorded approximately $37.0 million
of goodwill within the Unregulated Energy reportable segment as of December 31, 2021, all of which relates to the four reporting
units listed above. To test goodwill for impairment, the Company uses a present value technique based on discounted cash flows
to estimate the fair value of its reporting units. Management’s testing of goodwill for December 31, 2021 indicated no
impairment.
We determined the goodwill impairment assessment for the four reporting units listed above was a critical audit matter because
the fair value estimates require significant estimates and assumptions by management, including those relating to future revenue
and operating margin forecasts and discount rates. Testing these estimates involved increased auditor judgment and effort.
How the Critical Audit Matter was Addressed in the Audit
The primary procedures we performed to address this critical audit matter included:
• We obtained an understanding, evaluated the design, and tested the operating effectiveness of controls over
management’s goodwill impairment evaluation, including those over the determination of the fair value of the reporting
units within the Unregulated Energy reportable segment.
• We evaluated the appropriateness of management’s valuation methodology, including testing the mathematical accuracy
of the calculation.
• We assessed the historical accuracy of management’s revenue and operating margin forecasts.
• We compared the significant assumptions used by management to current industry and economic trends, current and
historical performance of each reporting unit, and other relevant factors.
• We performed sensitivity analyses of the significant assumptions to evaluate the changes in the fair value of the reporting
units that would result from changes in the assumptions.
• We evaluated whether the assumptions were consistent with evidence obtained in other areas of the audit, including
testing the Company’s fair value of all reporting units, inclusive of the Regulated and Unregulated Energy reporting
units, in relation to the market capitalization of the Company and assessed the results.
Chesapeake Utilities Corporation 2021 Form 10-K Page 55
/s/ Baker Tilly US, LLP
We have served as the Company's auditor since 2007.
Philadelphia, Pennsylvania
February 23, 2022
Chesapeake Utilities Corporation 2021 Form 10-K Page 56
Chesapeake Utilities Corporation and Subsidiaries
Consolidated Statements of Income
(in thousands, except shares and per share data)
Operating Revenues
Regulated Energy
Unregulated Energy
Other businesses and eliminations
Total operating revenues
Operating Expenses
Natural gas and electricity costs
Propane and natural gas costs
Operations
Maintenance
Gain from a settlement
Depreciation and amortization
Other taxes
Total operating expenses
Operating Income
Other income (expense), net
Interest charges
Income from Continuing Operations Before Income Taxes
Income Taxes on Continuing Operations
Income from Continuing Operations
Income (loss) from Discontinued Operations, Net of Tax
Gain on sale of Discontinued Operations, Net of tax
Net Income
Weighted Average Common Shares Outstanding:
Basic
Diluted
Basic Earnings Per Share of Common Stock:
Earnings Per Share from Continuing Operations
Earnings Per Share from Discontinued Operations
Basic Earnings Per Share of Common Stock
Diluted Earnings Per Share of Common Stock:
Earnings Per Share from Continuing Operations
Earnings Per Share from Discontinued Operations
Diluted Earnings Per Share of Common Stock
For the Year Ended December 31,
2019
2020
2021
$
383,920 $
206,869
(20,821)
569,968
100,737
86,213
148,294
16,793
—
62,661
24,158
438,856
131,112
1,721
20,135
112,698
29,231
83,467
(1)
—
83,466 $
$
352,746 $
152,526
(17,074)
488,198
91,994
45,944
142,055
15,587
(130)
58,117
21,908
375,475
112,723
3,222
21,765
94,180
23,538
70,642
686
170
71,498 $
343,006
154,151
(17,552)
479,605
102,803
51,698
137,845
15,679
(130)
45,424
20,001
373,320
106,285
(1,847)
22,224
82,214
21,114
61,100
(1,349)
5,402
65,153
17,558,078 16,711,579 16,398,443
17,633,029 16,770,735 16,448,486
$
$
$
$
4.75 $
—
4.75 $
4.73 $
—
4.73 $
4.23 $
0.05
4.28 $
4.21 $
0.05
4.26 $
3.73
0.24
3.97
3.72
0.24
3.96
The accompanying notes are an integral part of the financial statements.
Chesapeake Utilities Corporation 2021 Form 10-K Page 57
Chesapeake Utilities Corporation and Subsidiaries
Consolidated Statements of Comprehensive Income
(in thousands)
Net Income
Other Comprehensive Income (Loss), net of tax:
Employee Benefits, net of tax:
Amortization of prior service cost, net of tax of $(20), $(18) and
$(20), respectively
Net gain (loss), net of tax of $662, $(41), and $368, respectively
Cash Flow Hedges, net of tax:
Unrealized gain (loss) on commodity contract cash flow hedges,
net of tax of $864, $1,392 and $(176), respectively
Unrealized gain (loss) on interest rate swap cash flow hedges, net
of tax of $12, $(12), and $0, respectively
Total Other Comprehensive Income
Comprehensive Income
For the Year Ended December 31,
2019
2020
2021
$
83,466 $
71,498 $
65,153
(57)
1,935
(59)
(154)
(57)
1,052
2,262
3,643
(434)
28
4,168
87,634 $
(28)
3,402
74,900 $
—
561
65,714
$
The accompanying notes are an integral part of the financial statements.
Chesapeake Utilities Corporation 2021 Form 10-K Page 58
Chesapeake Utilities Corporation and Subsidiaries
Consolidated Balance Sheets
Assets
(in thousands, except shares and per share data)
Property, Plant and Equipment
Regulated Energy
Unregulated Energy
Other businesses and eliminations
Total property, plant and equipment
Less: Accumulated depreciation and amortization
Plus: Construction work in progress
Net property, plant and equipment
Current Assets
Cash and cash equivalents
Trade and other receivables
Less: Allowance for credit losses
Trade receivables, net
Accrued revenue
Propane inventory, at average cost
Other inventory, at average cost
Regulatory assets
Storage gas prepayments
Income taxes receivable
Prepaid expenses
Derivative assets, at fair value
Other current assets
Total current assets
Deferred Charges and Other Assets
Goodwill
Other intangible assets, net
Investments, at fair value
Operating lease right-of-use assets
Regulatory assets
Receivables and other deferred charges
Total deferred charges and other assets
Total Assets
As of December 31,
2021
2020
1,720,287
357,259
35,418
2,112,964
(417,479)
49,393
1,744,878
4,976
61,623
(3,141)
58,482
22,513
11,644
9,345
19,794
3,691
17,460
17,121
7,076
1,033
173,135
44,708
13,192
12,095
10,139
104,173
12,549
196,856
2,114,869 $
1,577,576
300,647
30,769
1,908,992
(368,743)
60,929
1,601,178
3,499
61,675
(4,785)
56,890
21,527
5,906
5,539
10,786
2,455
12,885
13,239
3,269
436
136,431
38,731
8,292
10,776
11,194
113,806
12,079
194,878
1,932,487
$
$
The accompanying notes are an integral part of the financial statements.
Chesapeake Utilities Corporation 2021 Form 10-K Page 59
Chesapeake Utilities Corporation and Subsidiaries
Consolidated Balance Sheets
Capitalization and Liabilities
(in thousands, except shares and per share data)
Capitalization
Stockholders’ equity
Preferred stock, par value $0.01 per share (authorized 2,000,000 shares), no
shares issued and outstanding
Common stock, par value $0.4867 per share (authorized 50,000,000 shares)
Additional paid-in capital
Retained earnings
Accumulated other comprehensive income (loss)
Deferred compensation obligation
Treasury stock
$
Total stockholders’ equity
Long-term debt, net of current maturities
Total capitalization
Current Liabilities
Current portion of long-term debt
Short-term borrowing
Accounts payable
Customer deposits and refunds
Accrued interest
Dividends payable
Accrued compensation
Regulatory liabilities
Derivative liabilities, at fair value
Other accrued liabilities
Total current liabilities
Deferred Credits and Other Liabilities
Deferred income taxes
Regulatory liabilities
Environmental liabilities
Other pension and benefit costs
Operating lease - liabilities
Deferred investment tax credits and other liabilities
Total deferred credits and other liabilities
Environmental and other commitments and contingencies (Note 20 and 21)
As of December 31,
2021
2020
— $
8,593
371,162
393,072
1,303
7,240
(7,240)
774,130
549,903
1,324,033
17,962
221,634
52,628
36,488
2,775
8,466
15,505
2,312
743
17,920
376,433
233,550
142,488
3,538
24,120
8,571
2,136
414,403
—
8,499
348,482
342,969
(2,865)
5,679
(5,679)
697,085
508,499
1,205,584
13,600
175,644
60,253
33,302
2,905
7,683
13,994
6,284
127
15,240
329,032
205,388
142,736
4,299
30,673
9,872
4,903
397,871
Total Capitalization and Liabilities
$
2,114,869 $
1,932,487
The accompanying notes are an integral part of the financial statements.
Chesapeake Utilities Corporation 2021 Form 10-K Page 60
Chesapeake Utilities Corporation and Subsidiaries
Consolidated Statements of Cash Flows
(in thousands)
Operating Activities
Net Income
Adjustments to reconcile net income to net operating cash:
Depreciation and amortization
Depreciation and accretion included in operations expenses
Deferred income taxes, net
Gain on sale of discontinued operations
Realized (loss) on sale of assets/commodity contracts
Unrealized (gain) on investments/commodity contracts
Employee benefits and compensation
Share-based compensation
Changes in assets and liabilities:
Accounts receivable and accrued revenue
Propane inventory, storage gas and other inventory
Regulatory assets/liabilities, net
Prepaid expenses and other current assets
Accounts payable and other accrued liabilities
Income taxes receivable
Customer deposits and refunds
Accrued compensation
Other assets and liabilities, net
Net cash provided by operating activities
Investing Activities
Property, plant and equipment expenditures
Proceeds from sale of assets
Acquisitions, net of cash acquired
Proceeds from the sale of discontinued operations
Environmental expenditures
Net cash used in investing activities
Financing Activities
Common stock dividends
Issuance of stock for Dividend Reinvestment Plan
Proceeds from issuance of common stock, net of expenses
Tax withholding payments related to net settled stock compensation
Change in cash overdrafts due to outstanding checks
Net borrowings (repayments) under line of credit agreements
Proceeds from issuance of long-term debt
Repayment of long-term debt and finance lease obligation
Net cash provided by financing activities
Net (Decrease) Increase in Cash and Cash Equivalents
Cash and Cash Equivalents — Beginning of Period
Cash and Cash Equivalents — End of Period
Supplemental Cash Flow Disclosures (see Note 7)
For the Year Ended December 31,
2020
2019
2021
$
83,466 $
71,498 $
65,153
62,661
10,228
26,658
—
(9,026)
(1,464)
(53)
5,945
(1,634)
(9,517)
(18,464)
(1,520)
8,285
(4,575)
3,176
1,198
(4,860)
150,504
(186,924)
1,033
(36,371)
—
(761)
(223,023)
(31,537)
15,851
—
(1,478)
(1,154)
46,647
59,478
(13,811)
73,996
1,477
3,499
4,976 $
58,117
9,599
24,709
(200)
(6,243)
(1,482)
207
4,829
(7,426)
1,709
(4,973)
2,424
4,941
7,165
2,238
(2,473)
(5,723)
158,916
(165,511)
8,080
(22,231)
200
(2,169)
(181,631)
(27,161)
22,627
60,980
(977)
(825)
(71,637)
89,822
(53,600)
19,229
(3,486)
6,985
3,499 $
45,900
8,752
24,476
(7,344)
(4,135)
(1,595)
1,985
4,279
36,489
8,227
(7,812)
11,115
(62,021)
(4,750)
(1,811)
2,120
(16,064)
102,964
(184,727)
427
(23,988)
22,871
(1,170)
(186,587)
(24,693)
(721)
—
(692)
(1,174)
(45,913)
199,648
(41,936)
84,519
896
6,089
6,985
$
The accompanying notes are an integral part of the financial statements.
Chesapeake Utilities Corporation 2021 Form 10-K Page 61
Chesapeake Utilities Corporation and Subsidiaries
Consolidated Statements of Stockholders' Equity
(in thousands, except shares and per share
data)
Balance at December 31, 2018
Net Income
Prior period reclassification
Other comprehensive loss
Dividends declared ($1.585 per share)
Dividend reinvestment plan
Share-based compensation and tax benefit (3) (4)
Treasury stock activities(2)
Balance at December 31, 2019
Net Income
Other comprehensive income
Dividends declared ($1.725 per share)
Equity issuances under various plans (5)
Share-based compensation and tax benefit (3) (4)
Treasury stock activities (2)
Cumulative effect of the adoption of ASU
2016-13
Balances at December 31, 2020
Net Income
Other comprehensive income
Dividends declared ($1.880 per share)
Dividend reinvestment plan
Share-based compensation and tax benefit (3) (4)
Treasury stock activities (2)
Balances at December 31, 2021
Common Stock (1)
Number
of
Shares(2)
16,378,545 $
—
—
—
—
—
25,231
—
16,403,776
—
—
—
1,023,609
34,456
—
—
17,461,841
—
—
—
147,256
46,313
—
17,655,410 $
Par
Value
7,971 $
—
—
—
—
—
13
—
7,984
—
—
—
498
17
—
—
8,499
—
—
—
72
22
—
8,593 $
Additional
Paid-In
Capital
255,651 $
—
—
—
—
(3)
3,605
—
259,253
—
—
—
85,353
3,876
—
—
348,482
—
—
—
18,176
4,504
—
371,162 $
Retained
Earnings
261,530 $
65,153
115
—
(26,191)
—
—
—
300,607
71,498
—
(29,106)
—
—
—
(30)
342,969
83,466
—
(33,363)
—
—
—
393,072 $
Accumulated
Other
Comprehensive
Loss
Deferred
Compensation
3,854 $
—
—
—
—
—
—
689
4,543
—
—
—
—
—
1,136
—
5,679
—
—
—
—
—
1,561
7,240 $
(6,713) $
—
(115)
561
—
—
—
—
(6,267)
—
3,402
—
—
—
—
—
(2,865)
—
4,168
—
—
—
—
1,303 $
Treasury
Stock
(3,854) $
—
—
—
—
—
—
(689)
(4,543)
—
—
—
—
—
(1,136)
—
(5,679)
—
—
—
—
—
(1,561)
(7,240) $
Total
518,439
65,153
—
561
(26,191)
(3)
3,618
—
561,577
71,498
3,402
(29,106)
85,851
3,893
—
(30)
697,085
83,466
4,168
(33,363)
18,248
4,526
—
774,130
(1) 2,000,000 shares of preferred stock at $0.01 par value per share have been authorized. No shares have been issued or are outstanding; accordingly, no information has
been included in the Consolidated Statements of Stockholders’ Equity.
(2) Includes 116,238, 105,087 and 95,329 shares at December 31, 2021, 2020 and 2019, respectively, held in a Rabbi Trust related to our Non-Qualified Deferred
Compensation Plan.
(3) Includes amounts for shares issued for directors’ compensation.
(4) The shares issued under the SICP are net of shares withheld for employee taxes. For 2021, 2020 and 2019, we withheld 14,020, 10,319 and 7,635 shares, respectively,
for taxes.
(5) Includes the Retirement Savings Plan, DRIP and ATM equity issuances.
The accompanying notes are an integral part of the financial statements.
Chesapeake Utilities Corporation 2021 Form 10-K Page 62
Notes to the Consolidated Financial Statements
1. ORGANIZATION AND BASIS OF PRESENTATION
Chesapeake Utilities, incorporated in 1947 in Delaware, is a diversified energy company engaged in regulated and unregulated
energy businesses.
Our regulated energy businesses consist of: (a) regulated natural gas distribution operations in central and southern Delaware,
Maryland’s eastern shore and Florida; (b) regulated natural gas transmission operations on the Delmarva Peninsula, in
Pennsylvania and in Florida; and (c) regulated electric distribution operations serving customers in northeast and northwest
Florida.
Our unregulated energy businesses primarily include: (a) propane operations in the Mid-Atlantic region, North Carolina, South
Carolina, and Florida; (b) our unregulated natural gas transmission/supply operation in central and eastern Ohio; (c) our CHP
plant in Florida that generates electricity and steam; and (d) our subsidiary, based in Florida, that provides CNG, LNG and RNG
transportation and pipeline solutions, primarily to utilities and pipelines throughout the eastern United States.
Our consolidated financial statements include the accounts of Chesapeake Utilities and its wholly-owned subsidiaries. We do not
have any ownership interest in investments accounted for using the equity method or any interest in a variable interest entity. All
intercompany accounts and transactions have been eliminated in consolidation. We have assessed and, if applicable, reported on
subsequent events through the date of issuance of these consolidated financial statements. Where necessary to improve
comparability, prior period amounts have been changed to conform to current period presentation.
Beginning in the third quarter of 2019, our management began executing a strategy to sell the operating assets of PESCO. In the
fourth quarter of 2019, we closed on four separate transactions to sell PESCO's assets and contracts. As a result of these sales, we
have fully exited the natural gas marketing business. Accordingly, PESCO’s historical financial results are reflected in our
consolidated financial statements as discontinued operations, which required retrospective application to financial information
for all periods presented. Refer to Note 4, Acquisitions for further information.
Effects of COVID-19
In March 2020, the CDC declared a national emergency due to the rapidly growing outbreak of COVID-19. In response to this
declaration and the rapid spread of COVID-19 within the United States, federal, state and local governments throughout the
country imposed varying degrees of restrictions on social and commercial activity to promote social distancing in an effort to
slow the spread of the illness. These restrictions significantly impacted economic conditions in the United States in 2020 and
continued into 2021. Chesapeake Utilities is considered an “essential business,” which has allowed us to continue operational
activities and construction projects while adhering to the social distancing restrictions that were in place.
Throughout 2021, restrictions continued to be lifted as vaccines have become widely available in the United States. For example,
the state of emergency in Florida was terminated in May 2021 followed by Delaware and Maryland in July 2021, resulting in
reduced restrictions. The expiration of the states of emergency in our service territories, along with the settlement of our limited
proceeding in Florida, has concluded our ability to defer incremental pandemic related costs for consideration through the
applicable regulatory process.
We have been closely following the legal process related to the Occupational Safety and Health Administration (OSHA)
Emergency Temporary Standard (ETS) mandating that all employers, with 100 or more employees, require COVID-19
vaccinations or weekly testing, which made its way to the United States Supreme Court. While OSHA has withdrawn the ETS as
a temporary standard following the Supreme Court’s ruling, we will continue to monitor its status as a proposed rule, and any
developments in the various appeals of the various district court orders enjoining the enforcement of the Executive Order
regarding the federal contractor vaccine mandate. In light of the continued emergence and growing prevalence of the new variants
of COVID-19, such as the Omicron variant, we continue to operate under our pandemic response plan, monitor developments
affecting employees, customers, suppliers, and stockholders and take all precautions warranted to operate safely and to comply
with the CDC and OSHA standards, in order to protect our employees, customers and the communities we serve. Refer to Note
19, Rates and Other Regulatory Activities, for further information on the regulated assets established as a result of the incremental
expenses associated with COVID-19.
Chesapeake Utilities Corporation 2021 Form 10-K Page 63
Notes to the Consolidated Financial Statements
2. SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES
Use of Estimates
The preparation of the consolidated financial statements in conformity with GAAP requires management to make estimates in
measuring assets and liabilities and related revenues and expenses. These estimates involve judgments about various future
economic factors that are difficult to predict and are beyond our control; therefore, actual results could differ from these estimates.
As additional information becomes available, or actual amounts are determined, recorded estimates are revised. Consequently,
operating results can be affected by revisions to prior accounting estimates.
Property, Plant and Equipment
Property, plant and equipment are stated at original cost less accumulated depreciation or fair value, if impaired. Costs include
direct labor, materials and third-party construction contractor costs, allowance for funds used during construction ("AFUDC"),
and certain indirect costs related to equipment and employees engaged in construction. The costs of repairs and minor
replacements are charged to expense as incurred, and the costs of major renewals and betterments are capitalized. Upon retirement
or disposition of property within the regulated businesses, the gain or loss, net of salvage value, is charged to accumulated
depreciation. Upon retirement or disposition of property owned by the unregulated businesses, the gain or loss, net of salvage
value, is charged to income. A summary of property, plant and equipment for continuing operations by classification as of
December 31, 2021 and 2020 is provided in the following table:
(in thousands)
Property, plant and equipment
Regulated Energy
As of December 31,
2020
2021
Natural gas distribution - Delmarva Peninsula and Florida
Natural gas transmission - Delmarva Peninsula, Pennsylvania and Florida
Electric distribution
$
859,627 $
727,277
133,383
782,329
667,538
127,710
Unregulated Energy
Propane operations – Mid-Atlantic, North Carolina, South Carolina and Florida
Natural gas transmission and supply – Ohio
Electricity and steam generation
Mobile CNG and pipeline solutions
Other
Total property, plant and equipment
Less: Accumulated depreciation and amortization
Plus: Construction work in progress
Net property, plant and equipment
Contributions or Advances in Aid of Construction
176,095
112,050
36,740
32,374
35,418
2,112,964
(417,479)
49,393
151,258
87,962
36,521
24,905
30,769
1,908,992
(368,743)
60,929
$ 1,744,878 $ 1,601,178
Customer contributions or advances in aid of construction reduce property, plant and equipment, unless the amounts are
refundable to customers. Contributions or advances may be refundable to customers after a number of years based on the amount
of revenues generated from the customers or the duration of the service provided to the customers. Refundable contributions or
advances are recorded initially as liabilities. Non-refundable contributions reduce property, plant and equipment at the time of
such determination. As of December 31, 2021 and 2020, the non-refundable contributions totaled $6.3 million and $3.7 million,
respectively.
Chesapeake Utilities Corporation 2021 Form 10-K Page 64
Notes to the Consolidated Financial Statements
AFUDC
Some of the additions to our regulated property, plant and equipment include AFUDC, which represents the estimated cost of
funds, from both debt and equity sources, used to finance the construction of major projects. AFUDC is capitalized in the
applicable rate base for ratemaking purposes when the completed projects are placed in service. During the years ended
December 31, 2021, 2020 and 2019 AFUDC totaled $0.4 million, $0.7 million and $0.7 million, respectively, which was reflected
as a reduction of interest charges.
Leases
We have entered into lease arrangements for office space, land, equipment, pipeline facilities and warehouses. These leases enable
us to conduct our business operations in the regions in which we operate. Our operating leases are included in operating lease
right-of-use assets, other accrued liabilities, and operating lease - liabilities in our consolidated balance sheets.
Right-of-use assets represent our right to use an underlying asset for the lease term and lease liabilities represent our obligation
to make lease payments arising from the lease. Operating lease right-of-use assets and liabilities are recognized at commencement
date based on the present value of lease payments over the lease term. Leases with an initial term of 12 months or less are not
recorded on our balance sheet; we recognize lease expense for these leases on a straight-line basis over the lease term. Our leases
do not provide an implicit lease rate, therefore, we utilize our incremental borrowing rate, as the basis to calculate the present
value of future lease payments, at lease commencement. Our incremental borrowing rate represents the rate that we would have
to pay to borrow funds on a collateralized basis over a similar term and in a similar economic environment.
We have lease agreements with lease and non-lease components. At the adoption of ASC 842, we elected not to separate non-
lease components from all classes of our existing leases. The non-lease components have been accounted for as part of the single
lease component to which they are related. See Note 15, Leases, for additional information.
Jointly-owned Pipelines
Property, plant and equipment for our Florida natural gas transmission operation included $27.6 million of assets at December 31,
2021, which consist of the 26-mile Callahan intrastate transmission pipeline in Nassau County, Florida jointly-owned with
Seacoast Gas Transmission. Peninsula Pipeline's ownership is 50 percent. The pipeline was placed in-service during the second
quarter of 2020. Peninsula Pipeline's share of direct expenses for the jointly-owned pipeline are included in operating expenses
of our consolidated statements of income. Accumulated depreciation for this pipeline totaled $0.9 million at December 31, 2021.
Property, plant and equipment for our Florida natural gas transmission operation also included $6.7 million of assets, at
December 31, 2021 and 2020, which consisted of the 16-mile pipeline from the Duval/Nassau County line to Amelia Island in
Nassau County, Florida, previously jointly owned with Peoples Gas. Effective October 2020, the parties agreed to terminate the
pre-existing ownership and capacity agreement and rescind their ownership interests in exchange for defined sections of the
pipeline. This resulted in Peninsula Pipeline taking a 100% ownership in the northern end of the pipeline. Accumulated
depreciation for this pipeline totaled $1.8 million and $1.7 million at December 31, 2021 and 2020, respectively.
Chesapeake Utilities Corporation 2021 Form 10-K Page 65
Notes to the Consolidated Financial Statements
Impairment of Long-lived Assets
We periodically evaluate whether events or circumstances have occurred, which indicate that other long-lived assets may not be
fully recoverable. The determination of whether an impairment has occurred is based on an estimate of undiscounted future cash
flows attributable to the asset, compared to the carrying value of the asset. When such events or circumstances are present, we
record an impairment loss equal to the excess of the asset's carrying value over its fair value, if any.
Depreciation and Accretion Included in Operations Expenses
We compute depreciation expense for our regulated operations by applying composite, annual rates, as approved by the respective
regulatory bodies. The following table shows the average depreciation rates used for regulated operations during the years ended
December 31, 2021, 2020 and 2019:
Natural gas distribution – Delmarva Peninsula
Natural gas distribution – Florida
Natural gas transmission – Delmarva Peninsula
Natural gas transmission – Florida
Electric distribution
2021
2.5%
2.5%
2.7%
2.3%
2.8%
2020
2.5%
2.5%
2.7%
2.3%
2.9%
2019
2.5%
2.6%
2.6%
2.4%
3.4%
For our unregulated operations, we compute depreciation expense on a straight-line basis over the following estimated useful
lives of the assets:
Asset Description
Propane distribution mains
Propane bulk plants and tanks
Propane equipment, meters and meter installations
Measuring and regulating station equipment
Natural gas pipelines
Natural gas right of ways
CHP plant
Natural gas processing equipment
Office furniture and equipment
Transportation equipment
Structures and improvements
Other
Useful Life
10-37 years
10-40 years
5-33 years
5-37 years
45 years
Perpetual
30 years
20-25 years
3-10 years
4-20 years
5-45 years
Various
We report certain depreciation and accretion in operations expense, rather than as a depreciation and amortization expense, in the
accompanying consolidated statements of income in accordance with industry practice and regulatory requirements. Depreciation
and accretion included in operations expense consists of the accretion of the costs of removal for future retirements of utility
assets, vehicle depreciation, computer software and hardware depreciation, and other minor amounts of depreciation expense.
For the years ended December 31, 2021, 2020 and 2019, we reported $10.2 million, $9.6 million and $8.8 million, respectively,
of depreciation and accretion in operations expenses.
Chesapeake Utilities Corporation 2021 Form 10-K Page 66
Notes to the Consolidated Financial Statements
Regulated Operations
We account for our regulated operations in accordance with ASC Topic 980, Regulated Operations, which includes accounting
principles for companies whose rates are determined by independent third-party regulators. When setting rates, regulators often
make decisions, the economics of which require companies to defer costs or revenues in different periods than may be appropriate
for unregulated enterprises. When this situation occurs, a regulated company defers the associated costs as regulatory assets on
the balance sheet and records them as expense on the income statement as it collects revenues. Further, regulators can also impose
liabilities upon a regulated company, for amounts previously collected from customers and for recovery of costs that are expected
to be incurred in the future, as regulatory liabilities. If we were required to terminate the application of these regulatory provisions
to our regulated operations, all such deferred amounts would be recognized in the statement of income at that time, which could
have a material impact on our financial position, results of operations and cash flows.
We monitor our regulatory and competitive environments to determine whether the recovery of our regulatory assets continues
to be probable. If we determined that recovery of these assets is no longer probable, we would write off the assets against earnings.
We believe that the provisions of ASC Topic 980, Regulated Operations, continue to apply to our regulated operations and that
the recovery of our regulatory assets is probable.
Revenue Recognition
Revenues for our natural gas and electric distribution operations are based on rates approved by the PSC in each state in which
they operate. Customers’ base rates may not be changed without formal approval by these commissions. The PSCs, however,
have authorized our regulated operations to negotiate rates, based on approved methodologies, with customers that have
competitive alternatives. Eastern Shore’s revenues are based on rates approved by the FERC. The FERC has also authorized
Eastern Shore to negotiate rates above or below the FERC-approved maximum rates, which customers can elect as an alternative
to FERC-approved maximum rates.
For regulated deliveries of natural gas and electricity, we read meters and bill customers on monthly cycles that do not coincide
with the accounting periods used for financial reporting purposes. We accrue unbilled revenues for natural gas and electricity
delivered, but not yet billed, at the end of an accounting period to the extent that they do not coincide. We estimate the amount of
the unbilled revenue by jurisdiction and customer class.
All of our regulated natural gas and electric distribution operations have fuel cost recovery mechanisms, except for two utilities
that provide only unbundled delivery service (Chesapeake Utilities' Central Florida Gas division and FPU's Indiantown division).
These mechanisms allow us to adjust billing rates, without further regulatory approvals, to reflect changes in the cost of purchased
fuel. Differences between the cost of fuel purchased and delivered are deferred and accounted for as either unrecovered fuel cost
or amounts payable to customers. Generally, these deferred amounts are recovered or refunded within one year.
We charge flexible rates to our natural gas distribution industrial interruptible customers who can use alternative fuels.
Interruptible service imposes no contractual obligation to deliver or receive natural gas on a firm service basis.
Our unregulated propane delivery businesses record revenue in the period the products are delivered and/or services are rendered
for their bulk delivery customers. For propane customers with meters whose billing cycles do not coincide with our accounting
periods, we accrue unbilled revenue for product delivered but not yet billed and bill customers at the end of an accounting period,
as we do in our regulated energy businesses.
Our Ohio natural gas transmission/supply operation recognizes revenues based on actual volumes of natural gas shipped using
contractual rates based upon index prices that are published monthly.
Eight Flags records revenues based on the amount of electricity and steam generated and sold to its customers.
Our mobile compressed natural gas operation recognizes revenue for CNG services at the end of each calendar month for services
provided during the month based on agreed upon rates for labor, equipment utilized, costs incurred for natural gas compression,
miles driven, mobilization and demobilization fees.
We report revenue taxes, such as gross receipts taxes, franchise taxes, and sales taxes, on a net basis.
Chesapeake Utilities Corporation 2021 Form 10-K Page 67
Notes to the Consolidated Financial Statements
Natural Gas, Electric and Propane Costs
Natural gas, electric and propane costs include the direct costs attributable to the products sold or services provided to our
customers. These costs include primarily the variable commodity cost of natural gas, electricity and propane, costs of pipeline
capacity needed to transport and store natural gas, transmission costs for electricity, costs to gather and process natural gas, costs
to transport propane to/from our storage facilities or our mobile CNG equipment to customer locations, and steam and electricity
generation costs. Depreciation expense is not included in natural gas, electric and propane costs.
Operations and Maintenance Expenses
Operations and maintenance expenses include operations and maintenance salaries and benefits, materials and supplies, usage of
vehicles, tools and equipment, payments to contractors, utility plant maintenance, customer service, professional fees and other
outside services, insurance expense, minor amounts of depreciation, accretion of removal costs for future retirements of utility
assets and other administrative expenses.
Cash and Cash Equivalents
Our policy is to invest cash in excess of operating requirements in overnight income-producing accounts. Such amounts are stated
at cost, which approximates fair value. Investments with an original maturity of three months or less when purchased are
considered cash equivalents.
Accounts Receivable and Allowance for Credit Losses
Accounts receivable consist primarily of amounts due for sales of natural gas, electricity and propane and transportation and
distribution services to customers. An allowance for doubtful accounts is recorded against amounts due based upon our collections
experiences and an assessment of our customers’ inability or reluctance to pay. If circumstances change, our estimates of
recoverable accounts receivable may also change. Circumstances which could affect such estimates include, but are not limited
to, customer credit issues, natural gas, electricity and propane prices and impacts from pandemics and general economic
conditions. Accounts receivable are written off when they are deemed to be uncollectible.
Our estimate for expected credit losses has been developed by analyzing our portfolio of financial assets that present potential
credit exposure risk. These assets consist solely of our trade receivables from customers and contract assets. The estimate is based
on five years of historical collections experience, a review of current economic and operating conditions in our service territories,
and an examination of economic indicators which provide a reasonable and supportable basis of potential future activity. Those
indicators include metrics which we believe provide insight into the future collectability of our trade receivables such as
unemployment rates and economic growth statistics in our service territories.
When determining estimated credit losses, we analyze the balance of our trade receivables based on the underlying line of
business. This resulted in an examination of trade receivables from our energy distribution, energy transmission, energy delivery
services and propane operations businesses. Our energy distribution business consists of all our regulated distribution utility
(natural gas and electric) operations on the Delmarva Peninsula and in Florida. These business units have the ability to recover
their costs through the rate making process, which can include consideration for amounts historically written off to be included
in rate base. Therefore, they possess a mechanism to recover credit losses which we believe reduces their exposure to credit risk.
Our energy transmission and energy delivery services business units consist of our natural gas pipelines and our mobile CNG
delivery operations. The majority of customers served by these business units are regulated distribution utilities who also have
the ability to recover their costs. We believe this cost recovery mechanism significantly reduces the amount of credit risk. Our
propane operations are unregulated and do not have the same ability to recover their costs as our regulated operations. However,
historically our propane operations have not had material write offs relative to the amount of revenues generated.
Our estimate of expected credit losses reflects our anticipated losses associated with our trade receivables as a result of non-
payment from our customers beginning the day the trade receivable is established. We believe the risk of loss associated with
trade receivables classified as current presents the least amount of credit exposure risk and therefore, we assign a lower estimate
to our current trade receivables. As our trade receivables age outside of their expected due date, our estimate increases. Our
allowance for credit losses relative to the balance of our trade receivables has historically been immaterial as a result of on time
payment activity from our customers.
Chesapeake Utilities Corporation 2021 Form 10-K Page 68
Notes to the Consolidated Financial Statements
During the first quarter of 2020, COVID-19 began to rapidly spread within the United States. Federal, state and local governments
throughout the country imposed restrictions to promote social distancing to slow the spread of the virus, which has also had the
effect of limiting commercial activity. These measures resulted in significant job losses and a slowing of economic activity across
the United States and in the areas that we serve. We have considered the impact of COVID-19 on our receivables for the twelve
months ended December 31, 2021, monitored developments that impact our customers’ ability to pay and have revised our
estimates of expected credit losses to reflect these impacts.
(in thousands)
Balance at December 31, 2020
Additions:
Provision for credit losses
Recoveries
Deductions:
Write offs
Balance at December 31, 2021
Inventories
$
$
4,785
134
(125)
(1,653)
3,141
We use the average cost method to value propane, materials and supplies, and other merchandise inventory. If market prices drop
below cost, inventory balances that are subject to price risk are adjusted to their net realizable value. There was no lower-of-cost-
or-net realizable value adjustment for the years ended December 31, 2021, 2020 or 2019.
Goodwill and Other Intangible Assets
Goodwill is not amortized but is tested for impairment at least annually, or more frequently if an event occurs or circumstances
change that would more likely than not reduce the fair value of a reporting unit below its carrying value. We use a present value
technique based on discounted cash flows to estimate the fair value of our reporting units. An impairment charge is recognized if
the carrying value of a reporting unit’s goodwill exceeds its implied fair value. The testing of goodwill for the years ended
December 31, 2021, 2020 and 2019 indicated no goodwill impairment. Other intangible assets are amortized on a straight-line
basis over their estimated economic useful lives.
Other Deferred Charges
Other deferred charges include issuance costs associated with short-term borrowings. These charges are amortized over the life
of the related short-term debt borrowings.
Asset Removal Cost
As authorized by the appropriate regulatory body (state PSC or FERC), we accrue future asset removal costs associated with
utility property, plant and equipment even if a legal obligation does not exist. Such accruals are provided for through depreciation
expense and are recorded with corresponding credits to regulatory liabilities or assets. When we retire depreciable utility plant
and equipment, we charge the associated original costs to accumulated depreciation and amortization, and any related removal
costs incurred are charged to regulatory liabilities or assets. The difference between removal costs recognized in depreciation
rates and the accretion and depreciation expense recognized for financial reporting purposes is a timing difference between
recovery of these costs in rates and their recognition for financial reporting purposes. Accordingly, these differences are deferred
as regulatory liabilities or assets. In the rate setting process, the regulatory liability or asset is excluded from the rate base upon
which those utilities have the opportunity to earn their allowed rates of return. The costs associated with our asset retirement
obligations are either currently being recovered in rates or are probable of recovery in future rates.
Chesapeake Utilities Corporation 2021 Form 10-K Page 69
Notes to the Consolidated Financial Statements
Pension and Other Postretirement Plans
Pension and other postretirement plan costs and liabilities are determined on an actuarial basis and are affected by numerous
assumptions and estimates, including the fair value of plan assets, estimates of the expected returns on plan assets, assumed
discount rates, the level of contributions made to the plans, and current demographic and actuarial mortality data. We review
annually the estimates and assumptions underlying our pension and other postretirement plan costs and liabilities with the
assistance of third-party actuarial firms. The assumed discount rates, expected returns on plan assets and the mortality assumption
are the factors that generally have the most significant impact on our pension costs and liabilities. The assumed discount rates,
health care cost trend rates and rates of retirement generally have the most significant impact on our postretirement plan costs
and liabilities.
The discount rates are utilized principally in calculating the actuarial present value of our pension and postretirement obligations
and net pension and postretirement costs. When estimating our discount rates, we consider high-quality corporate bond rates,
such as the Prudential curve index and the FTSE Index, changes in those rates from the prior year and other pertinent factors,
including the expected life of each of our plans and their respective payment options.
The expected long-term rates of return on assets are utilized in calculating the expected returns on the plan assets component of
our annual pension plan costs. We estimate the expected returns on plan assets by evaluating expected bond returns, asset
allocations, the effects of active plan management, the impact of periodic plan asset rebalancing and historical performance. We
also consider the guidance from our investment advisors in making a final determination of our expected rates of return on assets.
We estimate the health care cost trend rates used in determining our postretirement net expense based upon actual health care cost
experience, the effects of recently enacted legislation and general economic conditions. Our assumed rate of retirement is
estimated based upon our annual reviews of participant census information as of the measurement date.
The mortality assumption used for our pension and postretirement plans is reviewed periodically and is based on the actuarial
table that best reflects the expected mortality of the plan participants.
Income Taxes, Investment Tax Credit Adjustments and Tax-Related Contingency
Deferred tax assets and liabilities are recorded for the income tax effect of temporary differences between the financial statement
basis and tax basis of assets and liabilities and are measured using the enacted income tax rates in effect in the years in which the
differences are expected to reverse. Deferred tax assets are recorded net of any valuation allowance when it is more likely than
not that such income tax benefits will be realized. Investment tax credits on utility property have been deferred and are allocated
to income ratably over the lives of the subject property.
We account for uncertainty in income taxes in our consolidated financial statements only if it is more likely than not that an
uncertain tax position is sustainable based on technical merits. Recognizable tax positions are then measured to determine the
amount of benefit recognized in the consolidated financial statements. We recognize penalties and interest related to unrecognized
tax benefits as a component of other income.
We account for contingencies associated with taxes other than income when the likelihood of a loss is both probable and estimable.
In assessing the likelihood of a loss, we do not consider the existence of current inquiries, or the likelihood of future inquiries, by
tax authorities as a factor. Our assessment is based solely on our application of the appropriate statutes and the likelihood of a
loss, assuming the proper inquiries are made by tax authorities.
Financial Instruments
We utilize financial instruments to mitigate commodity price risk associated with fluctuations of natural gas, electricity and
propane and to mitigate interest rate risk. Our propane operations enter into derivative transactions, such as swaps, put options
and call options in order to mitigate the impact of wholesale price fluctuations on inventory valuation and future purchase
commitments. These transactions may be designated as fair value hedges or cash flow hedges, if they meet all of the accounting
requirements pursuant to ASC Topic 815, Derivatives and Hedging, and we elect to designate the instruments as hedges. If
designated as a fair value hedge, the value of the hedging instrument, such as a swap, future, or put option, is recorded at fair
value, with the effective portion of the gain or loss of the hedging instrument effectively reducing or increasing the value of the
hedged item. If designated as a cash flow hedge, the value of the hedging instrument, such as a swap or call option, is recorded
Chesapeake Utilities Corporation 2021 Form 10-K Page 70
Notes to the Consolidated Financial Statements
at fair value with the effective portion of the gain or loss of the hedging instrument being recorded in comprehensive income. The
ineffective portion of the gain or loss of a hedge is recorded in earnings. If the instrument is not designated as a fair value or cash
flow hedge, or it does not meet the accounting requirements of a hedge under ASC Topic 815, Derivatives and Hedging, it is
recorded at fair value with all gains or losses being recorded directly in earnings.
Our natural gas, electric and propane operations enter into agreements with suppliers to purchase natural gas, electricity, and
propane for resale to our respective customers. Purchases under these contracts, as well as distribution and sales agreements with
counterparties or customers, either do not meet the definition of a derivative, or qualify for “normal purchases and sales” treatment
under ASC Topic 815 Derivatives and Hedging, and are accounted for on an accrual basis.
We manage interest rate risk by entering into derivative contracts to hedge the variability in cash flows attributable to changes in
the short-term borrowing rates. We designate and account for the interest rate swaps as cash flows hedges. Accordingly, unrealized
gains and losses associated with the interest rate swaps are recorded as a component of accumulated other comprehensive income
(loss). When the interest rate swaps settle, the realized gain or loss will be recorded in the income statement and recognized as a
component of interest charges.
Recently Adopted Accounting Standards
There are no new accounting pronouncements issued that are applicable to us.
3. EARNINGS PER SHARE
The following table presents the calculation of our basic and diluted earnings per share:
(in thousands, except shares and per share data)
Calculation of Basic Earnings Per Share:
Income from Continuing Operations
Income/(Loss) from Discontinued Operations
Net Income
Weighted average shares outstanding
Earnings Per Share from Continuing Operations
Earnings Per Share from Discontinued Operations
Basic Earnings Per Share
Calculation of Diluted Earnings Per Share:
Reconciliation of Denominator:
Weighted average shares outstanding — Basic
Effect of dilutive securities — Share-based compensation
Adjusted denominator — Diluted
Earnings Per Share from Continuing Operations
Earnings Per Share from Discontinued Operations
Diluted Earnings Per Share
For the Year Ended December 31,
2019
2020
2021
$
$
83,467 $
(1)
83,466 $
70,642 $
856
71,498 $
61,100
4,053
65,153
17,558,078 16,711,579 16,398,443
3.73
$
0.24
3.97
4.23 $
0.05
4.28 $
4.75 $
—
4.75 $
$
59,156
74,951
17,558,078 16,711,579 16,398,443
50,043
17,633,029 16,770,735 16,448,486
3.72
$
0.24
3.96
4.21 $
0.05
4.26 $
4.73 $
—
4.73 $
$
Chesapeake Utilities Corporation 2021 Form 10-K Page 71
Notes to the Consolidated Financial Statements
4. ACQUISITIONS
Acquisition of Diversified Energy
On December 15, 2021, Sharp acquired the propane operating assets of Diversified Energy for approximately $37.5 million, net
of cash acquired. In connection with this acquisition, we recorded a $2.1 million liability which is subject to the seller's adherence
to various provisions contained in the purchase agreement through the first anniversary of the transaction closing. Included with
the acquisition, was approximately $1.7 million of working capital from the Seller consisting predominantly of accounts
receivable and propane inventory. We accounted for this acquisition as a business combination within our Unregulated Energy
Segment beginning in the fourth quarter of 2021. There are multiple strategic benefits to this acquisition including it: (i) expands
our propane service territory into North Carolina, South Carolina, Pennsylvania, and Virginia and (ii) includes an established
customer base with opportunities for future growth. Through this acquisition, the Company expands its operating footprint into
North Carolina and South Carolina and our propane business will add approximately 19,000 residential, commercial and
agricultural customers, along with distribution of approximately 10.0 million gallons of propane annually. In connection with this
acquisition, we recorded $23.1 million in property plant and equipment, $6.2 million in intangible assets associated with customer
relationships and non-compete agreements and $5.9 million in goodwill, all of which is deductible for income tax purposes. The
amounts recorded in conjunction with the acquisition are preliminary, and subject to adjustment based on contractual provisions.
In January 2022, we received a $0.8 million customary post-closing working capital true-up provision related to the working
capital valuation at the time of closing.
Acquisition of Western Natural Gas
In October 2020, Sharp acquired certain propane operating assets of Western Natural Gas, which provides propane distribution
service throughout Jacksonville, Florida and the surrounding communities, for approximately $6.7 million, net of cash acquired.
Additionally, the purchase price included $0.3 million of working capital. We accounted for this acquisition as a business
combination within our Unregulated Energy Segment beginning in the fourth quarter of 2020. There are multiple strategic benefits
to this acquisition including: (i) expansion of our propane service territory in Florida and (ii) establishment of a customer base
with additional opportunities for future growth.
In connection with this acquisition, we recorded $3.5 million in property plant and equipment, $1.4 million in intangible assets
associated with customer relationships and non-compete agreements and $1.8 million in goodwill, all of which is deductible for
income tax purposes.
Acquisition of Elkton Gas
In July 2020, we closed on the acquisition on of Elkton Gas, which provides natural gas distribution service to approximately
7,000 residential and commercial customers within a franchised area of Cecil County, Maryland for approximately $15.6 million,
net of cash acquired. Additionally, the purchase price included $0.6 million of working capital. Elkton Gas’ territory is contiguous
to our franchised service territory in Cecil County, Maryland.
In connection with this acquisition, we recorded $15.9 million in property, plant and equipment, $0.6 million in accounts
receivable, $2.6 million in other liabilities, $2.6 million in regulatory liabilities and $4.3 million in goodwill, all of which is
deductible for income tax purposes. All of the assets and liabilities are recorded in the Regulated Energy segment. Upon reaching
the end of the acquisition measurement period, we recognized offsetting adjustments to the acquisition date fair values of several
of the assets acquired and liabilities assumed. These adjustments did not materially impact our previously recognized amount of
goodwill.
Chesapeake Utilities Corporation 2021 Form 10-K Page 72
Notes to the Consolidated Financial Statements
These acquisitions generated the following operating revenues and income:
For the Year Ended
December 31, 2021
For the Year Ended
December 31, 2020
Operating Revenues
Operating Income
Operating Revenues Operating Income
(in thousands)
Diversified Energy
$
Western Natural Gas $
Elkton Gas
$
5. REVENUE RECOGNITION
1,423 $
2,594 $
7,105 $
300
$
550 $
1,000 $
— $
555 $
2,399 $
—
120
418
We recognize revenue when our performance obligations under contracts with customers have been satisfied, which generally
occurs when our businesses have delivered or transported natural gas, electricity or propane to customers. We exclude sales taxes
and other similar taxes from the transaction price. Typically, our customers pay for the goods and/or services we provide in the
month following the satisfaction of our performance obligation. The following tables display revenue from continuing operations
by major source based on product and service type for the years ended December 31, 2021, 2020 and 2019:
Chesapeake Utilities Corporation 2021 Form 10-K Page 73
Notes to the Consolidated Financial Statements
(in thousands)
Energy distribution
Delaware natural gas division
$
Florida natural gas division
FPU electric distribution
FPU natural gas distribution
Maryland natural gas division
Sandpiper natural gas/propane operations
Elkton Gas
Total energy distribution
Energy transmission
Aspire Energy
Aspire Energy Express
Eastern Shore
Peninsula Pipeline
Total energy transmission
Energy generation
Eight Flags
Propane operations
Propane delivery operations
Energy delivery services
Marlin Gas Services
Other and eliminations
Eliminations
Other
Total other and eliminations
Total operating revenues (1)
For the year ended December 31, 2021
Regulated
Energy
Unregulated
Energy
Other and
Eliminations
Total
71,195 $
34,074
78,300
100,535
22,449
20,746
7,105
334,404
—
187
76,911
26,630
103,728
— $
—
—
—
—
—
—
—
38,163
—
—
—
38,163
— $
—
—
—
—
—
—
—
—
—
—
—
—
71,195
34,074
78,300
100,535
22,449
20,746
7,105
334,404
38,163
187
76,911
26,630
141,891
—
18,652
—
18,652
—
142,082
—
142,082
—
8,315
—
8,315
(54,212)
—
(54,212)
(343)
—
(343)
(21,348)
527
(20,821)
(75,903)
527
(75,376)
$
383,920 $
206,869 $
(20,821) $
569,968
(1) Total operating revenues for the year ended December 31, 2021, include other revenue (revenues from sources other than contracts with customers) of $0.2
million and $0.4 million for our Regulated and Unregulated Energy segments, respectively. The sources of other revenues include revenue from alternative
revenue programs related to revenue normalization for Maryland division and Sandpiper and late fees.
Chesapeake Utilities Corporation 2021 Form 10-K Page 74
Notes to the Consolidated Financial Statements
(in thousands)
Energy distribution
Delaware natural gas division
Florida natural gas division
FPU electric distribution
FPU natural gas distribution
Maryland natural gas division
Sandpiper natural gas/propane operations
Elkton Gas
Total energy distribution
Energy transmission
Aspire Energy
Aspire Energy Express
Eastern Shore
Peninsula Pipeline
Total energy transmission
Energy generation
Eight Flags
Propane operations
Propane delivery operations
Energy delivery services
Marlin Gas Services
Other and eliminations
Eliminations
Other
Total other and eliminations
For the year ended December 31, 2020
Regulated
Energy
Unregulated
Energy
Other and
Eliminations
Total
$
63,389 $
— $
— $
63,389
30,850
76,863
90,150
21,853
17,214
2,399
302,718
—
16
75,117
23,080
98,213
—
—
—
—
—
—
—
—
—
—
27,951
—
—
—
27,951
16,147
100,744
7,818
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
(48,185)
—
(48,185)
(134)
—
(134)
(17,602)
528
(17,074)
30,850
76,863
90,150
21,853
17,214
2,399
302,718
27,951
16
75,117
23,080
126,164
16,147
100,744
7,818
(65,921)
528
(65,393)
Total operating revenues (1)
$
352,746 $
152,526 $
(17,074) $
488,198
(1) Total operating revenues for the year ended December 31, 2020, include other revenue (revenues from sources other than contracts with customers of $1.4
million and $0.2 million for our Regulated and Unregulated Energy segments, respectively. The sources of other revenues include revenue from alternative
revenue programs related to revenue normalization for Maryland division and Sandpiper and late fees.
Chesapeake Utilities Corporation 2021 Form 10-K Page 75
Notes to the Consolidated Financial Statements
(in thousands)
Energy distribution
Delaware natural gas division
Florida natural gas division
FPU electric distribution
FPU natural gas distribution
Maryland natural gas division
Sandpiper natural gas/propane operations
Total energy distribution
Energy transmission
Aspire Energy
Aspire Energy Express
Eastern Shore
Peninsula Pipeline
Total energy transmission
Energy generation
Eight Flags
Propane operations
Propane delivery operations
Energy delivery services
Marlin Gas Services
Other and eliminations
Eliminations
Other
Total other and eliminations
Total operating revenues (1)
For the years ended December 31, 2019
Regulated
Energy
Unregulated
Energy
Other and
Eliminations
Total
$
62,659 $
— $
— $
28,485
77,416
82,418
22,517
19,068
292,563
—
—
72,924
16,453
89,377
—
—
—
(38,934)
—
(38,934)
—
—
—
—
—
—
32,493
—
—
—
32,493
16,749
109,614
5,702
(10,407)
—
(10,407)
—
—
—
—
—
—
—
—
—
—
—
—
—
—
(18,081)
529
(17,552)
62,659
28,485
77,416
82,418
22,517
19,068
292,563
32,493
—
72,924
16,453
121,870
16,749
109,614
5,702
(67,422)
529
(66,893)
$
343,006
$
154,151
$
(17,552)
$
479,605
(1) Total operating revenues for the year ended December 31, 2019, include other revenue (revenues from sources other than contracts with customers) of $(0.1)
million and $0.3 million for our Regulated and Unregulated Energy segments, respectively. The sources of other revenues include revenue from alternative
revenue programs related to revenue normalization for Maryland division and Sandpiper and late fees.
Regulated Energy Segment
The businesses within our Regulated Energy segment are regulated utilities whose operations and customer contracts are subject
to rates approved by the respective state PSC or the FERC.
Our energy distribution operations deliver natural gas or electricity to customers, and we bill the customers for both the delivery
of natural gas or electricity and the related commodity, where applicable. In most jurisdictions, our customers are also required
to purchase the commodity from us, although certain customers in some jurisdictions may purchase the commodity from a third-
party retailer (in which case we provide delivery service only). We consider the delivery of natural gas or electricity and/or the
related commodity sale as one performance obligation because the commodity and its delivery are highly interrelated with two-
way dependency on one another. Our performance obligation is satisfied over time as natural gas or electricity is delivered and
consumed by the customer. We recognize revenues based on monthly meter readings, which are based on the quantity of natural
gas or electricity used and the approved rates. We accrue unbilled revenues for natural gas and electricity that have been delivered,
but not yet billed, at the end of an accounting period, to the extent that billing and delivery do not coincide.
Chesapeake Utilities Corporation 2021 Form 10-K Page 76
Notes to the Consolidated Financial Statements
Revenues for Eastern Shore are based on rates approved by the FERC. The FERC has also authorized Eastern Shore to negotiate
rates above or below the FERC-approved maximum rates, which customers can elect as an alternative to the FERC-approved
maximum rates. Eastern Shore's services can be firm or interruptible. Firm services are offered on a guaranteed basis and are
available at all times unless prevented by force majeure or other permitted curtailments. Interruptible customers receive service
only when there is available capacity or supply. Our performance obligation is satisfied over time as we deliver natural gas to the
customers' locations. We recognize revenues based on capacity used or reserved and the fixed monthly charge.
Peninsula Pipeline is engaged in natural gas intrastate transmission to third-party customers and certain affiliates in the State of
Florida. Our performance obligation is satisfied over time as the natural gas is transported to customers. We recognize revenue
based on rates approved by the Florida PSC and the capacity used or reserved. We accrue unbilled revenues for transportation
services provided and not yet billed at the end of an accounting period.
Aspire Energy Express is engaged in natural gas intrastate transmission in the State of Ohio. We currently serve the Guernsey
power plant and our performance obligation is satisfied over time as the natural gas is transported to the plant. We recognize
revenue based on rates approved by the Ohio PSC and the capacity used or reserved. We accrue unbilled revenues for
transportation services provided and not yet billed at the end of an accounting period.
Unregulated Energy Segment
Revenues generated from the Unregulated Energy segment are not subject to any federal, state, or local pricing regulations. Aspire
Energy primarily sources gas from hundreds of conventional producers and performs gathering and processing functions to
maintain the quality and reliability of its gas for its wholesale customers. Aspire Energy's performance obligation is satisfied over
time as natural gas is delivered to its customers. Aspire Energy recognizes revenue based on the deliveries of natural gas at
contractually agreed upon rates (which are based upon an established monthly index price and a monthly operating fee, as
applicable). For natural gas customers, we accrue unbilled revenues for natural gas that has been delivered, but not yet billed, at
the end of an accounting period, to the extent that billing and delivery do not coincide with the end of the accounting period.
Eight Flags' CHP plant, which is located on land leased from a customer, produces three sources of energy: electricity, steam and
heated water. This customer purchases the steam (unfired and fired) and heated water, which are used in the customer’s production
facility. Our electric distribution operation purchases the electricity generated by the CHP plant for distribution to its customers.
Eight Flags' performance obligation is satisfied over time as deliveries of heated water, steam and electricity occur. Eight Flags
recognizes revenues over time based on the amount of heated water, steam and electricity generated and delivered to its customers.
For our propane operations, we recognize revenue based upon customer type and service offered. Generally, for propane bulk
delivery customers (customers without meters) and wholesale sales, our performance obligation is satisfied when we deliver
propane to the customers' locations (point-in-time basis). We recognize revenue from these customers based on the number of
gallons delivered and the price per gallon at the point-in-time of delivery. For our propane delivery customers with meters, we
satisfy our performance obligation over time when we deliver propane to customers. We recognize revenue over time based on
the amount of propane consumed and the applicable price per unit. For propane delivery metered customers, we accrue unbilled
revenues for propane that has been delivered, but not yet billed, at the end of an accounting period, to the extent that billing and
delivery do not coincide with the end of the accounting period.
Marlin Gas Services provides mobile CNG and pipeline solutions primarily to utilities and pipelines. Marlin Gas Services
provides temporary hold services, pipeline integrity services, emergency services for damaged pipelines and specialized gas
services for customers who have unique requirements. Marlin Gas Services' performance obligations are comprised of the
compression of natural gas, mobilization of CNG equipment, utilization of equipment and on-site CNG support. Our performance
obligations for the compression of natural gas, utilization of mobile CNG equipment and for the on-site CNG staff support are
satisfied over time when the natural gas is compressed, equipment is utilized or as our staff provide support services to our
customers. Our performance obligation for the mobilization of CNG equipment is satisfied at a point-in-time when the equipment
is delivered to the customer project location. We recognize revenue for CNG services at the end of each calendar month for
services provided during the month based on agreed upon rates for equipment utilized, costs incurred for natural gas compression,
miles driven, mobilization and demobilization fees.
Chesapeake Utilities Corporation 2021 Form 10-K Page 77
Notes to the Consolidated Financial Statements
Contract balances
The timing of revenue recognition, customer billings and cash collections results in trade receivables, unbilled receivables
(contract assets), and customer advances (contract liabilities) in our consolidated balance sheets. The balances of our trade
receivables, contract assets, and contract liabilities as of December 31, 2021 and 2020 were as follows:
(in thousands)
Balance at 12/31/2020
Balance at 12/31/2021
Increase (decrease)
Trade
Receivables
Contract Assets
(Noncurrent)
Contract Liabilities
(Current)
$
$
55,600 $
56,277
677 $
4,816 $
4,806
(10) $
644
747
103
Our trade receivables are included in trade and other receivables in the consolidated balance sheets. Our non-current contract
assets are included in receivables and other deferred charges in the consolidated balance sheet and relate to operations and
maintenance costs incurred by Eight Flags that have not yet been recovered through rates for the sale of electricity to our electric
distribution operation pursuant to a long-term service agreement.
At times, we receive advances or deposits from our customers before we satisfy our performance obligation, resulting in contract
liabilities. Contract liabilities are included in other accrued liabilities in the consolidated balance sheets and relate to non-
refundable prepaid fixed fees for our Mid-Atlantic propane delivery operation's retail offerings. Our performance obligation is
satisfied over the term of the respective retail offering plan on a ratable basis. For the years ended December 31, 2021 and 2020,
we recognized revenue of $1.1 million and $1.3 million, respectively.
Remaining performance obligations
Our businesses have long-term fixed fee contracts with customers in which revenues are recognized when performance
obligations are satisfied over the contract term. Revenue for these businesses for the remaining performance obligations at
December 31, 2021 are expected to be recognized as follows:
(in thousands)
Eastern Shore and Peninsula Pipeline
Natural gas distribution operations
FPU electric distribution
Total revenue contracts with remaining
performance obligations
Practical expedients
2023
2022
2024
$ 33,925 $ 26,334 $ 24,103 $ 23,231 $ 21,964 $
5,946 5,410 5,179
275
275
6,174
652
6,747
652
652
2025
2026
2027 and
thereafter
179,866
33,543
550
$ 41,324 $ 33,160 $ 30,701 $ 28,916 $ 27,418 $
213,959
For our businesses with agreements that contain variable consideration, we use the invoice practical expedient method. We
determined that the amounts invoiced to customers correspond directly with the value to our customers and our performance to
date.
6. SEGMENT INFORMATION
We use the management approach to identify operating segments. We organize our business around differences in regulatory
environment and/or products or services, and the operating results of each segment are regularly reviewed by the chief decision
maker (our Chief Executive Officer) in order to make decisions about resources and to assess performance.
Our operations are entirely domestic and are comprised of two reportable segments:
Chesapeake Utilities Corporation 2021 Form 10-K Page 78
Notes to the Consolidated Financial Statements
•
•
Regulated Energy. Includes energy distribution and transmission services (natural gas distribution, natural gas
transmission and electric distribution operations). All operations in this segment are regulated, as to their rates and
services, by the PSC having jurisdiction in each operating territory or by the FERC in the case of Eastern Shore.
Unregulated Energy. Includes energy transmission, energy generation (the operations of our Eight Flags' CHP plant),
propane operations, and mobile compressed natural gas distribution and pipeline solutions operations. Also included in
this segment are other unregulated energy services, such as energy-related merchandise sales and heating, ventilation
and air conditioning, plumbing and electrical services. These operations are unregulated as to their rates and services.
The remainder of our operations are presented as “Other businesses and eliminations,” which consists of unregulated subsidiaries
that own real estate leased to Chesapeake Utilities, as well as certain corporate costs not allocated to other operations.
The following table presents information about our reportable segments.
For the Year Ended December 31,
2020
2019
2021
(in thousands)
Operating Revenues, Unaffiliated Customers
Regulated Energy
Unregulated Energy
Total operating revenues, unaffiliated customers
Intersegment Revenues (1)
Regulated Energy
Unregulated Energy
Other businesses
Total intersegment revenues
Operating Income (Loss)
Regulated Energy
Unregulated Energy
Other businesses and eliminations
Operating Income
Other income (expense), net
Interest charges
Income from Continuing Operations before Income Taxes
Income Taxes on Continuing Operations
Income from Continuing Operations
Income (loss) from Discontinued Operations, Net of Tax
Gain on sale of Discontinued Operations, Net of tax
Net Income
Depreciation and Amortization
Regulated Energy
Unregulated Energy
Other businesses and eliminations
Total depreciation and amortization
Capital Expenditures
Regulated Energy
Unregulated Energy
Other businesses
Total capital expenditures
$
$
$
$
$
$
$
$
$
$
381,879 $
188,089
569,968 $
350,853 $
137,345
488,198 $
340,857
138,748
479,605
2,041 $
18,780
527
21,348 $
1,893 $
15,181
528
17,602 $
2,149
15,403
529
18,081
106,064 $
24,382
666
131,112
1,721
20,135
112,698
29,231
83,467
(1)
—
92,124 $
20,664
(65)
112,723
3,222
21,765
94,180
23,538
70,642
686
170
86,584
19,938
(237)
106,285
(1,847)
22,224
82,214
21,114
61,100
(1,349)
5,402
83,466 $
71,498 $
65,153
48,748 $
13,869
44
62,661 $
46,079 $
11,988
50
58,117
$
35,227
10,130
67
45,424
$
139,733
81,651
6,425
227,809 $
147,100 $
46,295
2,480
195,875 $
130,604
60,034
8,348
198,986
Chesapeake Utilities Corporation 2021 Form 10-K Page 79
Notes to the Consolidated Financial Statements
(1) All significant intersegment revenues are billed at market rates and have been eliminated from consolidated revenues.
Identifiable Assets
Regulated Energy segment
Unregulated Energy segment
Other businesses and eliminations
Total identifiable assets
As of December 31,
2020
2021
$ 1,629,191 $ 1,547,619
347,665
37,203
$ 2,114,869 $ 1,932,487
439,114
46,564
7. SUPPLEMENTAL CASH FLOW DISCLOSURES
Cash paid for interest and income taxes during the years ended December 31, 2021, 2020 and 2019 were as follows:
(in thousands)
Cash paid for interest
Cash (received) paid for income taxes, net of refunds
For the Year Ended December 31,
2019
2020
2021
$
$
20,809 $
8,395 $
22,884 $
(8,135) $
23,856
3,221
Non-cash investing and financing activities during the years ended December 31, 2021, 2020, and 2019 were as follows:
(in thousands)
Capital property and equipment acquired on account, but not paid for as of
December 31
Common stock issued for the Retirement Savings Plan
Common stock issued under the SICP
$
$
$
For the Year Ended December 31,
2019
2020
2021
16,164 $
1,712 $
2,834 $
23,625 $
1,605 $
1,971 $
13,470
—
1,691
8. DERIVATIVE INSTRUMENTS
We use derivative and non-derivative contracts to manage risks related to obtaining adequate supplies and the price fluctuations
of natural gas, electricity and propane and to mitigate interest rate risk. Our natural gas, electric and propane distribution
operations have entered into agreements with suppliers to purchase natural gas, electricity and propane for resale to our customers.
Our natural gas gathering and transmission company has entered into contracts with producers to secure natural gas to meet its
obligations. Purchases under these contracts typically either do not meet the definition of derivatives or are considered “normal
purchases and normal sales” and are accounted for on an accrual basis. Our propane distribution operations may also enter into
fair value hedges of their inventory or cash flow hedges of their future purchase commitments in order to mitigate the impact of
wholesale price fluctuations. Occasionally, we may enter into interest rate swap agreements to mitigate risk associated with
changes in short-term borrowing rates. As of December 31, 2021 and 2020, our natural gas and electric distribution operations
did not have any outstanding derivative contracts.
Chesapeake Utilities Corporation 2021 Form 10-K Page 80
Notes to the Consolidated Financial Statements
Volume of Derivative Activity
As of December 31, 2021, the volume of our open commodity derivative contracts were as follows:
Business unit
Sharp
Sharp
Sharp
Commodity
Propane (gallons)
Propane (gallons)
Propane (gallons)
Contract Type
Purchases
Sales
Purchases
Quantity hedged
(in millions)
21.2
4.4
0.3
Designation
Cash flow hedges
Cash flow hedges
N/A
Longest expiration
date of hedge
June, 2024
December, 2022
March 2022
Sharp entered into futures and swap agreements to mitigate the risk of fluctuations in wholesale propane index prices associated
with the propane volumes expected to be purchased and/or sold during the heating season. Under the futures and swap agreements,
Sharp will receive or pay the difference between (i) the index prices (Mont Belvieu prices in December 2021 through June 2024)
and (ii) the per gallon propane contracted prices, to the extent the index prices deviate from the contracted prices. If the index
prices are lower than the contract prices, Sharp will pay the difference. We designated and accounted for the propane swaps as
cash flows hedges. The change in the fair value of the swap agreements is recorded as unrealized gain (loss) in other
comprehensive income (loss) and later recognized in the statement of income in the same period and in the same line item as the
hedged transaction. We expect to reclassify approximately $3.6 million of unrealized gain from accumulated other comprehensive
income to earnings during the next 12-month period ending December 31, 2022.
Interest Rate Swap Activities
We manage interest rate risk by entering into derivative contracts to hedge the variability in cash flows attributable to changes in
the short-term borrowing rates. In the second quarter of 2020, we entered into interest rate swaps with notional amounts totaling
$100.0 million associated with three of our short-term lines of credit which expired in October 2020. The interest rate swaps were
entered to hedge the variability in cash flows attributable to changes in the short-term borrowing rates during this period. Pricing
on the interest rate swaps ranged between 0.2615 and 0.3875 percent for the period. In the fourth quarter of 2020, we entered into
additional interest rate swaps with notional amount of $60.0 million through December 2021 with pricing of 0.20 percent and
0.205 percent for the period associated with our outstanding borrowing under the Revolver. In February 2021, we entered into
an additional interest rate swap with a notional amount of $40.0 million through December 2021 with pricing of 0.17 percent.
Our short-term borrowing is based on the 30-day LIBOR rate. The interest swap was cash settled monthly as the counter-party
pays us the 30-day LIBOR rate less the fixed rate. At December 31, 2021 all of our interest rate swaps had expired and we have
not entered into any new derivative contracts associated with our outstanding short-term borrowings.
Broker Margin
Futures exchanges have contract specific margin requirements that require the posting of cash or cash equivalents relating to
traded contracts. Margin requirements consist of initial margin that is posted upon the initiation of a position, maintenance margin
that is usually expressed as a percent of initial margin, and variation margin that fluctuates based on the daily mark-to-market
relative to maintenance margin requirements. We currently maintain a broker margin account for Sharp, the balance related to the
account is as follows:
(in thousands)
Sharp
Financial Statements Presentation
Balance Sheet Location
December 31,
2021
December 31,
2020
Other Current Liabilities
$
4,081 $
1,505
The following tables present information about the fair value and related gains and losses of our derivative contracts. We did not
have any derivative contracts with a credit-risk-related contingency. Fair values of the derivative contracts recorded in the
consolidated balance sheets as of December 31, 2021 and 2020 are as follows:
Chesapeake Utilities Corporation 2021 Form 10-K Page 81
Notes to the Consolidated Financial Statements
(in thousands)
Derivatives not designated as hedging instruments
Propane swap agreements
Derivatives designated as fair value hedges
Propane put options
Derivatives designated as cash flow hedges
Propane swap agreements
Total Derivative Assets
(in thousands)
Derivatives designated as fair value hedges
Propane put options
Derivatives designated as cash flow hedges
Propane swap agreements
Interest rate swap agreements
Total Derivative Liabilities
Derivative Assets
Fair Value as of
Balance Sheet Location
December 31, 2021
December 31, 2020
Derivative assets, at fair value
Derivative assets, at fair value
Derivative assets, at fair value
$
$
16 $
—
7,060
7,076 $
—
14
3,255
3,269
Derivative Liabilities
Fair Value as of
Balance Sheet Location
December 31, 2021
December 31, 2020
Derivative liabilities, at fair value
Derivative liabilities, at fair value
Derivative liabilities, at fair value
$
$
— $
743
—
743 $
23
64
40
127
The effects of gains and losses from derivative instruments are as follows:
Amount of Gain (Loss) on Derivatives:
For the Year Ended December 31,
2020
2021
2019
(1) $
(24)
—
(536)
7,187
3,126
(28)
—
—
—
9,724 $
— $
(12)
34
—
2,428
5,035
60
(40)
—
—
7,505 $
—
—
—
—
1,520
(253)
—
—
(63)
(294)
910
(in thousands)
Derivatives not designated as hedging
instruments
Propane swap agreements
Derivatives designated as fair value hedges
Put/Call option
Put/Call option
Derivatives designated as cash flow hedges
Propane swap agreements
Propane swap agreements
Propane swap agreements
Interest rate swap agreements
Interest rate swap agreements
Natural gas swap contracts
Natural gas futures contracts
Total
Location of Gain
(Loss) on Derivatives
Propane and natural gas costs
$
Propane and natural gas costs
Propane inventory
Revenues
Propane and natural gas costs
Other comprehensive income (loss)
Interest expense
Other comprehensive income (loss)
Other comprehensive income (loss)
Other comprehensive income (loss)
$
Chesapeake Utilities Corporation 2021 Form 10-K Page 82
Notes to the Consolidated Financial Statements
9. FAIR VALUE OF FINANCIAL INSTRUMENTS
GAAP establishes a fair value hierarchy that prioritizes the inputs to valuation methods used to measure fair value. The three
levels of the fair value hierarchy are the following:
Fair Value
Hierarchy
Description of Fair Value Level
Level 1 Unadjusted quoted prices in active
markets that are accessible at the
measurement date for identical,
unrestricted assets or liabilities
Level 2 Quoted prices in markets that are not
active, or inputs which are observable,
either directly or indirectly, for
substantially the full term of the asset or
liability
Level 3
Prices or valuation techniques requiring
inputs that are both significant to the fair
value measurement and unobservable
(i.e. supported by little or no market
activity)
Fair Value Technique Utilized
Investments - equity securities - The fair values of these
trading securities are recorded at fair value based on
unadjusted quoted prices in active markets for identical
securities.
Investments - mutual funds and other - The fair values of
these investments, comprised of money market and mutual
funds, are recorded at fair value based on quoted net asset
values of the shares.
Derivative assets and liabilities - The fair value of the
propane put/call options, propane and interest rate swap
agreements are measured using market transactions for similar
assets and liabilities in either the listed or over-the-counter
markets.
Investments - guaranteed income fund - The fair values of
these investments are recorded at the contract value, which
approximates their fair value.
Financial Assets and Liabilities Measured at Fair Value
The following tables summarize our financial assets and liabilities that are measured at fair value on a recurring basis and the fair
value measurements, by level, within the fair value hierarchy as of December 31, 2021 and 2020, respectively:
As of December 31, 2021
(in thousands)
Assets:
Investments—equity securities
Investments—guaranteed income fund
Investments—mutual funds and other
Total investments
Derivative assets
Total assets
Liabilities:
Derivative liabilities
Fair Value Measurements Using:
Significant Other
Observable
Inputs
(Level 2)
Significant
Unobservable
Inputs
(Level 3)
Quoted Prices in
Active Markets
(Level 1)
Fair Value
$
$
$
26 $
2,036
10,033
12,095
7,076
19,171 $
26 $
—
10,033
10,059
—
10,059 $
— $
—
—
—
7,076
7,076 $
—
2,036
—
2,036
—
2,036
743 $
— $
743 $
—
Chesapeake Utilities Corporation 2021 Form 10-K Page 83
Notes to the Consolidated Financial Statements
As of December 31, 2020
(in thousands)
Assets:
Investments—equity securities
Investments—guaranteed income fund
Investments—mutual funds and other
Total investments
Derivative assets
Total assets
Liabilities:
Derivative liabilities
Fair Value Measurements Using:
Significant Other
Observable
Inputs
(Level 2)
Significant
Unobservable
Inputs
(Level 3)
Quoted Prices in
Active Markets
(Level 1)
Fair Value
$
$
$
21 $
2,156
8,599
10,776
3,269
14,045 $
21 $
—
8,599
8,620
—
8,620 $
— $
—
—
—
3,269
3,269 $
—
2,156
—
2,156
—
2,156
127 $
— $
127 $
—
The following table sets forth the summary of the changes in the fair value of Level 3 investments for the years ended
December 31, 2021 and 2020:
(in thousands)
Beginning Balance
Purchases and adjustments
Transfers/disbursements
Investment income
Ending Balance
For the Year Ended December 31,
2021
2020
$
$
2,156 $
88
(241)
33
2,036 $
803
261
1,065
27
2,156
Investment income from the Level 3 investments is reflected in other income (expense), net in the consolidated statements of
income.
At December 31, 2021 and 2020, there were no non-financial assets or liabilities required to be reported at fair value. We review
our non-financial assets for impairment at least on an annual basis, as required.
Other Financial Assets and Liabilities
Financial assets with carrying values approximating fair value include cash and cash equivalents and accounts receivable.
Financial liabilities with carrying values approximating fair value include accounts payable, other accrued liabilities and short-
term debt. The fair value of cash and cash equivalents is measured using the comparable value in the active market and
approximates its carrying value (Level 1 measurement). The fair value of short-term debt approximates the carrying value due to
its near-term maturities and because interest rates approximate current market rates (Level 3 measurement).
At December 31, 2021, long-term debt, which includes the current maturities but excludes debt issuance cost, had a carrying
value of $568.8 million, compared to the estimated fair value of $597.2 million. At December 31, 2020, long-term debt, which
includes the current maturities and debt issuance costs, had a carrying value of $523.0 million, compared to a fair value of $548.5
million. The fair value was calculated using a discounted cash flow methodology that incorporates a market interest rate based
on published corporate borrowing rates for debt instruments with similar terms and average maturities, and with adjustments for
duration, optionality, and risk profile. The valuation technique used to estimate the fair value of long-term debt would be
considered a Level 3 measurement.
See Note 17, Employee Benefit Plans, for fair value measurement information related to our pension plan assets.
Chesapeake Utilities Corporation 2021 Form 10-K Page 84
Notes to the Consolidated Financial Statements
10. INVESTMENTS
The investment balances at December 31, 2021 and 2020, consisted of the following:
(in thousands)
Rabbi trust (associated with the Non-Qualified Deferred Compensation Plan)
Investments in equity securities
Total
As of December 31,
2021
2020
$
$
12,069 $
26
12,095 $
10,755
21
10,776
We classify these investments as trading securities and report them at their fair value. For the years ended December 31, 2021,
2020 and 2019, we recorded net unrealized gains of $1.5 million, $1.5 million, and $1.6 million, respectively in other income
(expense), net in the consolidated statements of income related to these investments. For the investments in the Rabbi Trust, we
also have recorded an associated liability, which is included in other pension and benefit costs in the consolidated balance sheets
and is adjusted each period for the gains and losses incurred by the investments in the Rabbi Trust.
11. GOODWILL AND OTHER INTANGIBLE ASSETS
The carrying value of goodwill from continuing operations as of December 31, 2021 and 2020 was as follows:
(in thousands)
Balance at December 31, 2020
Additions (1)
Balance at December 31, 2021
Regulated Energy
7,617
$
Unregulated Energy
31,114
$
$
72
5,905
$
7,689
$
37,019
$
Total Goodwill
38,731
5,977
44,708
(1)Includes goodwill from the purchase of operating assets of Diversified Energy in December 2021 and Elkton Gas in the third quarter of 2020.
The annual impairment testing for the years 2021 and 2020 indicated no impairment of goodwill.
The carrying value and accumulated amortization of intangible assets subject to amortization as of December 31, 2021 and 2020
are as follows:
(in thousands)
Customer relationships (1)
Non-Compete agreements (1)
Patents
Other
Total
As of December 31,
2021
2020
Gross
Carrying
Amount
Accumulated
Amortization
Gross
Carrying
Amount
Accumulated
Amortization
$
$
16,814 $
2,431
452
270
19,967 $
5,125 $
1,078
354
218
6,775 $
10,680 $
2,375
452
270
13,777 $
4,269
768
236
212
5,485
(1) The customer relationship and non-compete agreements amounts include $6.1 million and less than $0.1 million, respectively, as a result of the purchase of the
operating assets of Diversified Energy in December 2021 and $1.3 million and $0.1 million, respectively, recorded as a result of the purchase of the
operating assets of Western Natural Gas in October 2020.
The customer relationships, non-compete agreements, patents and other intangible assets acquired in the purchases of the
operating assets of several companies are being amortized over a weighted average of 12 years. Amortization expense of
intangible assets for the year ended December 31, 2021, 2020 and 2019 was $1.3 million, $1.2 million and $0.8 million,
respectively. Amortization expense of intangible assets is expected to be $1.4 million for the year 2022, $1.3 million for the years
2023 through 2025, and $1.1 million for 2026.
Chesapeake Utilities Corporation 2021 Form 10-K Page 85
Notes to the Consolidated Financial Statements
12. INCOME TAXES
We file a consolidated federal income tax return. Income tax expense allocated to our subsidiaries is based upon their respective
taxable incomes and tax credits. State income tax returns are filed on a separate company basis in most states where we have
operations and/or are required to file. Our state returns for tax years after 2015 are subject to examination. At December 31, 2021,
the 2015 through 2019 federal income tax returns are under examination, and no report has been issued at this time.
We expect to have federal NOLs totaling $6.3 million and $12.2 million in 2019 and 2018 respectively upon the settlement of the
Internal Revenue Service examination described above. Under the CARES Act, discussed below, we elected to carry the losses
back to 2015 and 2013. For state income tax purposes, we had NOLs in various states of $14.6 million and $40.0 million as of
December 31, 2021 and 2020, respectively, almost all of which will expire in 2039. Excluding NOL from discontinued operations,
we have recorded deferred tax assets of $1.5 million and $1.6 million related to state NOL carry-forwards at December 31, 2021
and 2020, respectively. We have not recorded a valuation allowance to reduce the future benefit of the tax NOLs because we
believe they will be fully utilized.
Tax Law Changes
In March 2020, the CARES Act was signed into law and included several significant changes to the Internal Revenue Code. The
CARES Act includes certain tax relief provisions including the ability to carryback five years net operating losses arising in a tax
year beginning in 2018, 2019, or 2020. This provision allows a taxpayer to recover taxes previously paid at a 35 percent federal
income tax rate during tax years prior to 2018. In addition, the CARES Act removed the taxable income limitation to allow a tax
NOL to fully offset taxable income for tax years beginning before January 1, 2021. Our income tax expense for the years ended
December 31, 2021 and 2020 included a tax benefit of $0.9 million and $1.8 million, respectively, attributable to the tax NOL
carryback provided under the CARES Act for losses generated in 2018 and 2019 and then applied back to our 2013 and 2015 tax
years in which we paid federal income taxes at a 35 percent tax rate.
On December 22, 2017, President Trump signed into law the TCJA. Substantially all of the provisions of the TCJA were effective
for taxable years beginning on or after January 1, 2018. The provisions that significantly impacted us include the reduction of the
corporate federal income tax rate from 35 percent to 21 percent. Our federal income tax expense for periods beginning on January
1, 2018 and thereafter are based on the new federal corporate income tax rate. The TCJA included changes to the Internal Revenue
Code, which materially impacted our 2017 financial statements. ASC 740, Income Taxes, requires recognition of the effects of
changes in tax laws in the period in which the law is enacted. ASC 740 requires deferred tax assets and liabilities to be measured
at the enacted tax rate expected to apply when temporary differences are to be realized or settled. During 2018, we completed the
assessment of the impact of accounting for certain effects of the TCJA. At the date of enactment in 2017, we re-measured deferred
income taxes based upon the new corporate tax rate. See Note 19, Rates and Other Regulatory Activities, for further discussion
of the TCJA's impact on our regulated businesses.
Chesapeake Utilities Corporation 2021 Form 10-K Page 86
Notes to the Consolidated Financial Statements
The following tables provide: (a) the components of income tax expense in 2021, 2020, and 2019; (b) the reconciliation between
the statutory federal income tax rate and the effective income tax rate for 2021, 2020, and 2019 from continuing operations; and
(c) the components of accumulated deferred income tax assets and liabilities at December 31, 2021 and 2020.
(in thousands)
Current Income Tax Expense
Federal
State
Other
Total current income tax expense (benefit)
Deferred Income Tax Expense (1)
Property, plant and equipment
Deferred gas costs
Pensions and other employee benefits
FPU merger-related premium cost and deferred gain
Net operating loss carryforwards
Other
Total deferred income tax expense
Income Tax Expense from Continuing Operations
Income Tax Expense from Discontinued Operations
Total Income Tax
For the Year Ended December 31,
2019
2020
2021
$
2,775 $
(96)
(47)
2,632
(2,777) $
2,162
(47)
(662)
24,074
1,857
(655)
(351)
97
1,577
26,599
29,231
—
23,224
(714)
(75)
156
5,107
(3,498)
24,200
23,538
153
(2,252)
(491)
(47)
(2,790)
25,907
79
(454)
(278)
(3,772)
2,422
23,904
21,114
1,416
$
29,231 $
23,691 $
22,530
(1) Includes $8.2 million, $4.9 million, and $4.7 million of deferred state income taxes for the years 2021, 2020 and 2019, respectively.
(in thousands)
Reconciliation of Effective Income Tax Rates from Continuing
Operations
Federal income tax expense (1)
State income taxes, net of federal benefit
ESOP dividend deduction
CARES Act Tax Benefit
Depreciation
Other
Total Income Tax Expense from Continuing Operations
Effective Income Tax Rate from Continuing Operations
(1) Federal income taxes were calculated at 21 percent for 2021, 2020, and 2019.
For the Year Ended December 31,
2019
2020
2021
$
23,666
$
19,778
$
17,264
6,371
(180)
(919)
(15)
308
5,051
(218)
(1,841)
—
768
$
$
29,231
25.94 %
$
23,538
24.99 %
5,093
(173)
—
—
(1,070)
21,114
25.65 %
Chesapeake Utilities Corporation 2021 Form 10-K Page 87
Notes to the Consolidated Financial Statements
(in thousands)
Deferred Income Taxes
Deferred income tax liabilities:
Property, plant and equipment
Acquisition adjustment
Loss on reacquired debt
Deferred gas costs
Natural gas conversion costs
Storm reserve liability
Other
Total deferred income tax liabilities
Deferred income tax assets:
Pension and other employee benefits
Environmental costs
Net operating loss carryforwards
Storm reserve liability
Accrued expenses
Other
Total deferred income tax assets
Deferred Income Taxes Per Consolidated Balance Sheets
13. LONG-TERM DEBT
Our outstanding long-term debt is shown below:
(in thousands)
Uncollateralized Senior Notes:
5.93% note, due October 31, 2023
5.68% note, due June 30, 2026
6.43% note, due May 2, 2028
3.73% note, due December 16, 2028
3.88% note, due May 15, 2029
3.25% note, due April 30, 2032
3.48% note, due May 31, 2038
3.58% note, due November 30, 2038
3.98% note, due August 20, 2039
2.98% note, due December 20, 2034
3.00% note, due July 15, 2035
2.96% note, due August 15, 2035
2.49% notes Due January 25, 2037
Equipment security note
2.46% note, due September 24, 2031
Less: debt issuance costs
Total long-term debt
Less: current maturities
Total long-term debt, net of current maturities
Chesapeake Utilities Corporation 2021 Form 10-K Page 88
As of December 31,
2020
2021
$
$
224,034 $
6,266
183
2,366
5,529
5,783
6,301
250,462
5,354
996
1,490
448
4,843
3,781
16,912
233,550 $
199,287
6,618
201
509
5,379
7,073
5,587
224,654
4,636
1,064
1,587
409
6,153
5,417
19,266
205,388
As of December 31,
2021
2020
$
$
6,000 $
14,500
4,900
14,000
40,000
70,000
50,000
50,000
100,000
70,000
50,000
40,000
50,000
9,378
(913)
567,865
(17,962)
549,903 $
9,000
17,400
5,600
16,000
45,000
70,000
50,000
50,000
100,000
70,000
50,000
40,000
—
—
(901)
522,099
(13,600)
508,499
Notes to the Consolidated Financial Statements
Notes Purchase Agreement
On December 16, 2021, we agreed to issue and MetLife agreed to purchase 2.95 percent Senior Notes due March 15, 2042 in the
aggregate principal amount of $50 million. We expect to issue the Notes on or before March 15, 2022. The Company anticipates
using the proceeds received from the issuances of the Notes to reduce short-term borrowings under the Company’s revolving
credit facility and/or to fund capital expenditures. These Senior Notes, when issued, will have similar covenants and default
provisions as the existing senior notes, and will have an annual principal payment beginning in the eleventh year after the issuance.
Equipment Security Note
On September 24, 2021, we entered into an Equipment Financing Agreement with Banc of America Leasing & Capital, LLC to
issue $9.6 million in sustainable financing associated with the purchase of qualifying equipment by our subsidiary, Marlin Gas
Services. The equipment security note bears a 2.46 percent interest rate and has a term of 10 years. Under the terms of the
agreement, we granted a security interest in the equipment to the lender, to serve as collateral.
Annual maturities
Annual maturities and principal repayments of long-term debt are as follows:
Year
(in thousands)
Payments
Shelf Agreements
2022
2023
2024
2025
2026
Thereafter
Total
$
17,962 $
21,483 $
18,505 $
25,528 $
34,551 $
450,749 $ 568,778
We have entered into Shelf Agreements with Prudential and MetLife, whom are under no obligation to purchase any unsecured
debt. The following table summarizes our shelf agreements at December 31, 2021:
Total
Borrowing
Capacity
Less Amount
of Debt
Issued
Less Unfunded
Commitments
Remaining
Borrowing
Capacity
(in thousands)
Shelf Agreements (1)
Prudential Shelf Agreement
MetLife Shelf Agreement (2)
Total
(1) The Prudential and MetLife Shelf Agreements expire in April 2023 and May 2023, respectively.
(2) Unfunded commitments of $50 million reflects Senior Notes expected to be issued on or before March 15, 2022..
370,000 $
150,000
520,000 $
(220,000) $
—
(220,000) $
$
$
— $
(50,000)
(50,000) $
150,000
100,000
250,000
The Senior Notes, Shelf Agreements or Shelf Notes set forth certain business covenants to which we are subject when any note
is outstanding, including covenants that limit or restrict our ability, and the ability of our subsidiaries, to incur indebtedness, or
place or permit liens and encumbrances on any of our property or the property of our subsidiaries.
Uncollateralized Senior Notes
All of our Uncollateralized Senior Notes require periodic principal and interest payments as specified in each note. They also
contain various restrictions. The most stringent restrictions state that we must maintain equity of at least 40.0 percent of total
capitalization (including short-term borrowings), and the fixed charge coverage ratio must be at least 1.2 times. The most recent
Senior Notes issued since September 2013 also contain a restriction that we must maintain an aggregate net book value in our
regulated business assets of at least 50.0 percent of our consolidated total assets. Failure to comply with those covenants could
result in accelerated due dates and/or termination of the Senior Note agreements.
Certain Uncollateralized Senior Notes contain a “restricted payments” covenant as defined in the respective note agreements. The
most restrictive covenants of this type are included within the 5.93 percent Senior Note, due October 31, 2023. The covenant
provides that we cannot pay or declare any dividends or make any other restricted payments in excess of the sum of $10.0 million,
plus our consolidated net income accrued on and after January 1, 2003. As of December 31, 2021, the cumulative consolidated
Chesapeake Utilities Corporation 2021 Form 10-K Page 89
Notes to the Consolidated Financial Statements
net income base was $664.5 million, offset by restricted payments of $289.4 million, leaving $375.1 million of cumulative net
income free of restrictions. As of December 31, 2021, we were in compliance with all of our debt covenants.
14. SHORT-TERM BORROWINGS
We are authorized by our Board of Directors to borrow up to $400.0 million of short-term debt, as required. At December 31,
2021 and 2020, we had $221.6 million and $175.6 million, respectively, of short-term borrowings outstanding at a weighted
average interest rate of 0.83 percent and 1.28 percent, respectively.
In August 2021, we amended and restated our Revolver into a multi-tranche facility totaling $400.0 million with multiple
participating lenders. The two tranches of the facility consist of a $200.0 million 364-day short-term debt tranche and a $200.0
million five-year tranche, both of which have three one-year extension options, which can be authorized by our Chief Financial
Officer. We are eligible to establish the repayment term for individual borrowings under the five year tranche of the facility and
to the extent that an individual loan under the Revolver exceeded 12 months, the outstanding balance would be classified as a
component of long-term debt.
The availability of funds under the Revolver is subject to conditions specified in the credit agreement, all of which we currently
satisfy. These conditions include our compliance with financial covenants and the continued accuracy of representations and
warranties contained in these agreements. We are required by the financial covenants in the Revolver to maintain, at the end of
each fiscal year, a funded indebtedness ratio of no greater than 65 percent. As of December 31, 2021, we are in compliance with
this covenant.
The 364-day tranche of the Revolver expires in August 2022 and the five-year tranche expires in August 2026. Both tranches are
available to provide funds for our short-term cash needs to meet seasonal working capital requirements and to temporarily fund
portions of our capital expenditures. Borrowings under both tranches of the Revolver are subject to a pricing grid, including the
commitment fee and the interest rate charged. Our pricing is adjusted each quarter based upon a total indebtedness to total
capitalization ratio. As of December 31, 2021, the pricing under the 364-day tranche of the Revolver does not include an unused
commitment fee and maintains an interest rate of 0.70 percent over LIBOR. As of December 31, 2021, the pricing under the five-
year tranche of the Revolver included an unused commitment fee of 0.09 percent and an interest rate of 0.95 percent over LIBOR.
Our total available credit under the Revolver at December 31, 2021 was $173.1 million. As of December 31, 2021, we had issued
$5.3 million in letters of credit to various counterparties under the syndicated Revolver. These letters of credit are not included in
the outstanding short-term borrowings and we do not anticipate they will be drawn upon by the counterparties. The letters of
credit reduce the available borrowings under our syndicated Revolver.
In the fourth quarter of 2020, we entered into two $30.0 million interest rate swaps with a total notional amount of $60.0 million
through December 2021 with pricing of 0.20 percent and 0.205 percent for the period associated with our outstanding borrowing
under the Revolver. In February 2021, we entered into an additional interest rate swap with a notional amount of $40.0 million
through December 2021 with pricing of 0.17 percent. Our short-term borrowing is based on the 30-day LIBOR rate. At
December 31, 2021, all of our interest rate swaps had expired and we have not entered into any new derivative contracts associated
with our outstanding short-term borrowings.
15. LEASES
We have entered into lease arrangements for office space, land, equipment, pipeline facilities and warehouses. These lease
arrangements enable us to better conduct business operations in the regions in which we operate. Office space is leased to provide
adequate workspace for all our employees in several locations throughout our service territories. We lease land at various locations
throughout our service territories to enable us to inject natural gas into underground storage and distribution systems, for bulk
storage capacity, for our propane operations and for storage of equipment used in repairs and maintenance of our infrastructure.
Chesapeake Utilities Corporation 2021 Form 10-K Page 90
Notes to the Consolidated Financial Statements
We lease natural gas compressors to ensure timely and reliable transportation of natural gas to our customers. Additionally, we
lease a pipeline to deliver natural gas to an industrial customer in Polk County, Florida. We also lease warehouses to store
equipment and materials used in repairs and maintenance for our businesses.
Some of our leases are subject to annual changes in the Consumer Price Index (“CPI”). While lease liabilities are not re-measured
as a result of changes to the CPI, changes to the CPI are treated as variable lease payments and recognized in the period in which
the obligation for those payments was incurred. A 100-basis-point increase in CPI would not have resulted in material additional
annual lease costs. Most of our leases include options to renew, with renewal terms that can extend the lease term from one to 25
years or more. The exercise of lease renewal options is at our sole discretion. The amounts disclosed in our consolidated balance
sheet at December 31, 2021, pertaining to the right-of-use assets and lease liabilities, are measured based on our current
expectations of exercising our available renewal options. Our existing leases are not subject to any restrictions or covenants which
preclude our ability to pay dividends, obtain financing or enter into additional leases. As of December 31, 2021, we have not
entered into any leases, which have not yet commenced, that would entitle us to significant rights or create additional obligations.
The following table presents information related to our total lease cost included in our consolidated statements of income:
Year Ended
December 31,
( in thousands)
Operating lease cost (1)
Classification
Operations expense
2021
2020
$
2,064 $
2,029
(1) Includes short-term leases and variable lease costs, which are immaterial.
The following table presents the balance and classifications of our right-of-use assets and lease liabilities included in our
consolidated balance sheet at December 31, 2021 and 2020:
(in thousands)
Assets
Balance sheet classification
December 31, 2021
December 31, 2020
Operating lease assets
Operating lease right-of-use assets
Liabilities
Current
Operating lease liabilities
Other accrued liabilities
Noncurrent
Operating lease liabilities
Total lease liabilities
Operating lease - liabilities
$
$
$
10,139 $
11,194
1,996 $
8,571
10,567 $
1,747
9,872
11,619
The following table presents our weighted-average remaining lease term and weighted-average discount rate for our operating
leases at December 31, 2021 and 2020:
Weighted-average remaining lease term (in years)
Operating leases
Weighted-average discount rate
Operating leases
December 31, 2021
December 31, 2020
8.10
3.6 %
8.70
3.8 %
The following table presents additional information related to cash paid for amounts included in the measurement of lease
liabilities included in our consolidated statements of cash flows at December 31, 2021 and 2020:
(in thousands)
Operating cash flows from operating leases
Year Ended December 31,
2020
2021
$
1,996 $
1,956
Chesapeake Utilities Corporation 2021 Form 10-K Page 91
Notes to the Consolidated Financial Statements
The following table presents the future undiscounted maturities of our operating leases at December 31, 2021 and for each of
the next five years and thereafter:
(in thousands)
2022
2023
2024
2025
2026
Thereafter
Total lease payments
Less: Interest
Present value of lease liabilities
Operating Leases (1)
$
2,019
1,902
1,672
1,341
885
3,668
11,487
(920)
10,567
$
(1) Operating lease payments include $2.1 million related to options to extend lease terms that are reasonably certain of being exercised.
16. STOCKHOLDERS' EQUITY
Common Stock Issuances
In June 2020, we filed a shelf registration statement with the SEC to facilitate the issuance of our common stock. In August 2020,
we filed a prospectus supplement under the shelf registration statement for an ATM equity program under which we may issue
and sell shares of our common stock up to an aggregate offering price of $75.0 million. In the third and fourth quarters of 2020,
we issued 0.7 million shares of common stock at an average price per share of $82.93 and received net proceeds of approximately
$61.0 million, after deducting commissions and other fees of $1.5 million.
We maintain an effective shelf registration statement with the SEC for the issuance of shares under our DRIP. Depending on our
capital needs and subject to market conditions, in addition to other possible debt and equity offerings, we may issue additional
shares under the direct stock purchase component of the DRIP. In 2021, we issued just over 0.1 million shares at an average price
per share of $125.71 and received net proceeds of $15.2 million under the DRIP. In the third and fourth quarters of 2020, we
issued 0.3 million shares at an average price per share of $86.12 and received net proceeds of $22.0 million under the DRIP.
We used the net proceeds from the ATM equity program and the DRIP, after deducting the commissions or other fees and related
offering expenses payable by us, for general corporate purposes, including, but not limited to, financing of capital expenditures,
repayment of short-term debt, financing acquisitions, investing in subsidiaries, and general working capital purposes.
Accumulated Other Comprehensive Income (Loss)
Defined benefit pension and postretirement plan items, unrealized gains (losses) of our propane swap agreements and natural gas
swaps and futures contracts, designated as commodity contracts cash flow hedges, and the unrealized gains (losses) of our interest
rate swap agreements, designated as cash flow hedges, are the components of our accumulated other comprehensive loss. The
following table presents the changes in the balance of accumulated other comprehensive income (loss) for the years ended
December 31, 2021 and 2020. All amounts in the following tables are presented net of tax.
Chesapeake Utilities Corporation 2021 Form 10-K Page 92
Notes to the Consolidated Financial Statements
Defined Benefit
Pension and
Postretirement
Plan Items
Commodity
Contract Cash
Flow Hedges
Interest Rate
Swap Cash
Flow Hedges
Total
(in thousands)
As of December 31, 2019
$
Other comprehensive income (loss) before reclassifications
Amounts reclassified from accumulated other
comprehensive income (loss)
Net current-period other comprehensive income (loss)
As of December 31, 2020
Other comprehensive income before reclassifications
Amounts reclassified from accumulated other
comprehensive income (loss)
Net current-period other comprehensive income
As of December 31, 2021
(4,933) $
(578)
(1,334) $
5,400
— $
16
(6,267)
4,838
365
(213)
(5,146)
262
(1,757)
3,643
2,309
7,075
1,616
1,878
(3,268) $
(4,813)
2,262
4,571 $
$
(44)
(28)
(28)
—
28
28
— $
(1,436)
3,402
(2,865)
7,337
(3,169)
4,168
1,303
The following table presents amounts reclassified out of accumulated other comprehensive income (loss) for the years ended
December 31, 2021, 2020 and 2019. Deferred gains and losses of our commodity contracts cash flow hedges are recognized in
earnings upon settlement.
(in thousands)
Amortization of defined benefit pension and postretirement plan
items:
Prior service cost (1)
Net gain (1)
Total before income taxes
Income tax benefit (4)
Net of tax
Gains on commodity contracts cash flow hedges
Propane swap agreements (2)
Natural gas swaps (2)(3)
Natural gas futures (2)(3)
Total before income taxes
Income tax expense (4)
Net of tax
Gains and (losses) on interest rate swap cash flow hedges:
Interest rate swap agreements
Total before income taxes
Income tax expense (4)
Net of tax
Total reclassifications for the period
For the Year Ended December 31,
2020
2019
2021
$
$
$
$
$
$
$
77 $
(2,243)
(2,166)
550
(1,616) $
6,651 $
—
—
6,651
(1,838)
4,813 $
(28) $
(28)
—
(28) $
77 $
(592)
(515)
150
(365) $
2,428 $
—
—
2,428
(671)
1,757 $
60 $
60
(16)
44 $
77
(2,600)
(2,523)
656
(1,867)
1,520
7
2,096
3,623
(1,028)
2,595
—
—
—
—
3,169 $
1,436 $
728
(1) These amounts are included in the computation of net periodic benefits. See Note 17, Employee Benefit Plans, for additional details.
(2) These amounts are included in the effects of gains and losses from derivative instruments. See Note 8, Derivative Instruments, for additional details.
(3) PESCO's results are reflected as discontinued operations in our consolidated statements of income.
(4) The income tax benefit is included in income tax expense in the accompanying consolidated statements of income.
Chesapeake Utilities Corporation 2021 Form 10-K Page 93
Notes to the Consolidated Financial Statements
17. EMPLOYEE BENEFIT PLANS
We measure the assets and obligations of the defined benefit pension plans and other postretirement benefits plans to determine
the plans’ funded status as of the end of the year. We record as a component of other comprehensive income/loss or a regulatory
asset the changes in funded status that occurred during the year that are not recognized as part of net periodic benefit costs.
Defined Benefit Pension Plans
At December 31, 2021 we sponsored two defined benefit pension plans: the FPU Pension Plan and the Chesapeake SERP.
During the fourth quarter of 2021, we formally terminated the Chesapeake Pension Plan. Accordingly, a portion of the pension
settlement expense associated with the termination was allocated to our Regulated Energy operations and was recorded as
regulatory assets, previously approved in all of the impacted jurisdictions. The remaining portion of the pension settlement
expense totaling $0.6 million was recorded in other expense in our consolidated statement of income which reflected the amount
allocated to our Unregulated Energy operations or was deemed not recoverable through the regulatory process.
The FPU Pension Plan, a qualified plan, covers eligible FPU non-union employees hired before January 1, 2005 and union
employees hired before the respective union contract expiration dates in 2005 and 2006. Prior to the FPU merger, the FPU Pension
Plan was frozen with respect to additional years of service and additional compensation, effective December 31, 2009.
The Chesapeake SERP, a nonqualified plan, is comprised of two sub-plans. The first sub-plan was frozen with respect to additional
years of service and additional compensation as of December 31, 2004. Benefits under the Chesapeake SERP for the first sub-
plan were based on each participant’s years of service and highest average compensation, prior to the freezing of the plan. Active
participants on the date the Chesapeake SERP was frozen were credited with two additional years of service. The second sub-
plan provides fixed payments for several executives who joined the Company as a result of an acquisition and whose agreements
with the Company provided for this benefit.
The unfunded liability for all three plans at both December 31, 2021 and 2020, is included in the other pension and benefit costs
liability in our consolidated balance sheets.
Chesapeake Utilities Corporation 2021 Form 10-K Page 94
Notes to the Consolidated Financial Statements
The following schedules set forth the funded status at December 31, 2021 and 2020 and the net periodic cost for the years ended
December 31, 2021, 2020 and 2019 for the Chesapeake and FPU Pension Plans as well as the Chesapeake SERP:
At December 31,
(in thousands)
Change in benefit obligation:
Chesapeake
Pension Plan
FPU
Pension Plan
Chesapeake
SERP
2021
2020
2021
2020
2021
2020
Benefit obligation — beginning of year $ 6,146
141
(371)
(5,884)
(32)
Interest cost
Actuarial (gain) loss
Effect of settlement
Benefits paid
Benefit obligation — end of year
—
$70,366
$ 6,214
1,714
176
(1,953)
450
(612) —
(82) (3,097)
67,030
6,146
$ 65,304
2,085
6,069
—
(3,092)
$ 2,212
48
(12)
—
(152)
2,096
70,366
$ 2,157
63
144
—
(152)
2,212
Change in plan assets:
Fair value of plan assets — beginning of
year
Actual return on plan assets
Employer contributions
Effect of settlement
Benefits paid
Fair value of plan assets — end of year
4,609
(237)
1,544
(5,884)
(32)
—
4,630
55,966
4,246
369
1,597
304
(612) —
(82) (3,097)
58,712
4,609
49,703
6,581
2,774
—
(3,092)
55,966
—
—
152
—
(152)
—
—
—
152
—
(152)
—
Reconciliation:
Funded status
Accrued pension cost
Assumptions:
—
$ —
(1,537) (8,318)
$ (1,537) $ (8,318)
(14,400) (2,096)
$(14,400) $ (2,096)
(2,212)
$ (2,212)
Discount rate
Expected return on plan assets
2.50 %
3.50 %
2.25 %
3.50 %
2.75 %
6.00 %
2.50 %
6.00 %
2.50 %
— %
2.25 %
— %
Chesapeake
Pension Plan
FPU
Pension Plan
Chesapeake
SERP
2021(2)
2020 2019(1)
2021
2020
2019
2021 2020 2019
For the Years Ended
December 31,
(in thousands)
Components of net periodic
pension cost:
Interest cost
Expected return on assets
Amortization of actuarial
loss
Settlement expense
Net periodic pension cost
Amortization of pre-
merger regulatory asset
$ 141
(166)
257
1,810
2,042
—
Total periodic cost
Assumptions:
$ 2,042
$ 176
$1,714
$ 375
(157) (487) (3,306)
$2,085
$ 48
$2,452
(2,967) (2,770) —
$ 63
—
$ 74
—
243
203
465
391
1,982
2,261
612
—
(980)
505
552
—
—
(330) 187
28
—
76
20
—
83
85
58
217
—
$ 465
—
$2,261
—
$ (980)
543
—
$ (330) $ 730
—
$ 76
—
$ 83
—
$217
Discount rate
Expected return on plan
assets
2.25 % 3.00 % 3.00 % 2.50 %
3.25 %
4.25 % 2.25 % 3.00 % 4.00 %
3.50 % 3.50 % 6.00 % 6.00 %
6.00 %
6.50 % — % — % — %
Chesapeake Utilities Corporation 2021 Form 10-K Page 95
Notes to the Consolidated Financial Statements
(1) As a result of annuity purchases and lump sum payments associated with the de-risking of the Chesapeake Pension Plan, the discount rate for Chesapeake
Pension Plan was re-measured which triggered settlement accounting expense in the fourth quarter of 2019. We recorded an estimated $0.7 million for the
settlement expense in our consolidated statement of income which reflected a portion of the pension settlement expense that was deemed not recoverable
through the regulatory process.
(2) As a result of the termination of the Chesapeake Pension Plan in 2021, we recorded $0.6 million as the final settlement expense in our consolidated statement
of income which reflected a portion of the pension settlement expense that was deemed not recoverable through the regulatory process.
Included in the net periodic costs for the FPU Pension Plan for the year ended December 31, 2019 is amortization of the FPU
pension regulatory asset, which represents the portion attributable to FPU's regulated operations for the changes in funded status
that occurred, but were not recognized as part of net periodic cost, prior to the merger with Chesapeake Utilities in October 2009.
This was previously deferred as a regulatory asset to be recovered through rates pursuant to an order by the Florida PSC. As of
December 31, 2019, this regulatory asset was fully amortized. Excluding the service cost component, the other components of
the net periodic costs have been recorded or reclassified to other expense, net of tax, in the consolidated statements of income.
Our funding policy provides that payments to the trust of each qualified plan shall be equal to at least the minimum funding
requirements of the Employee Retirement Income Security Act of 1974. At December 31, 2021, there are no remaining assets in
the Chesapeake Pension Plan. The following schedule summarizes the assets of the FPU Pension Plan, by investment type, at
December 31, 2021, 2020 and 2019:
At December 31,
Asset Category
Equity securities
Debt securities
Other
Total
2021
FPU Pension Plan
2020
2019
52 %
38 %
10 %
100 %
54 %
37 %
9 %
100 %
53 %
37 %
10 %
100 %
The investment policy of the FPU Pension Plan is designed to provide the capital assets necessary to meet the financial obligations
of the plans. The investment goals and objectives are to achieve investment returns that, together with contributions, will provide
funds adequate to pay promised benefits to present and future beneficiaries of the plan, earn a competitive return to increasingly
fund a large portion of the plan’s retirement liabilities, minimize pension expense and cumulative contributions resulting from
liability measurement and asset performance, and maintain the appropriate mix of investments to reduce the risk of large losses
over the expected remaining life of the plan.
The following allocation range of asset classes is intended to produce a rate of return sufficient to meet the FPU Pension Plan’s
goals and objectives (this allocation range applied to the Chesapeake Pension Plan prior to the de-risking strategy executed during
the fourth quarter of 2019):
Asset Allocation Strategy
Minimum Allocation
Percentage
Maximum Allocation
Percentage
Asset Class
32 %
Domestic Equities (Large Cap, Mid Cap and Small Cap)
Foreign Equities (Developed and Emerging Markets)
25 %
40 %
Fixed Income (Inflation Bond and Taxable Fixed)
Diversifying Assets (High Yield Fixed Income, Commodities, and Real Estate)
19 %
10 %
Alternative Strategies (Long/Short Equity and Hedge Fund of Funds)
5 %
Cash
Due to periodic contributions and different asset classes producing varying returns, the actual asset values may temporarily move
outside of the intended ranges. The investments are monitored on a quarterly basis, at a minimum, for asset allocation and
performance. At December 31, 2021 and 2020, the assets of the Chesapeake Pension Plan and the FPU Pension Plan were
comprised of the following investments:
14 %
13 %
26 %
7 %
4 %
0 %
Chesapeake Utilities Corporation 2021 Form 10-K Page 96
Notes to the Consolidated Financial Statements
Asset Category
(in thousands)
Mutual Funds - Equity securities
U.S. Large Cap (1)
U.S. Mid Cap (1)
U.S. Small Cap (1)
International (2)
Alternative Strategies (3)
Mutual Funds - Debt securities
Fixed income (4)
High Yield (4)
Mutual Funds - Other
Commodities (5)
Real Estate (6)
Guaranteed deposit (7)
Total Pension Plan Assets in fair
value hierarchy
Fair Value Measurement Hierarchy
At December 31, 2021
Level 1 Level 2 Level 3
At December 31, 2020
Level 1 Level 2 Level 3
Total
Total
$ 4,302 $ — $ — $ 4,302 $ 3,615 $ — $ — $ 3,615
1,672
1,835
891
954
11,307
10,863
5,586
5,888
23,071
23,842
— —
— —
— —
— —
— —
1,672
891
11,307
5,586
23,071
—
—
—
—
—
1,835
954
10,863
5,888
23,842
—
—
—
—
—
19,551
3,014
22,565
—
—
—
—
—
—
19,551
3,014
22,565
21,563
2,606
24,169
— —
— —
— —
21,563
2,606
24,169
2,297
2,729
—
5,026
—
—
—
—
—
—
497
497
2,297
2,729
497
5,523
2,246
1,954
—
4,200
— —
— —
— 1,019
— 1,019
2,246
1,954
1,019
5,219
$51,433 $ — $
497
51,930 $ 51,440 $ — $ 1,019
52,459
6,782
$ 58,712
Investments measured at net asset
value (8)
Total Pension Plan Assets
(1) Includes funds that invest primarily in United States common stocks.
(2) Includes funds that invest primarily in foreign equities and emerging markets equities.
(3) Includes funds that actively invest in both equity and debt securities, funds that sell short securities and funds that provide long-term capital appreciation. The
funds may invest in debt securities below investment grade.
(4) Includes funds that invest in investment grade and fixed income securities.
(5) Includes funds that invest primarily in commodity-linked derivative instruments and fixed income securities.
(6) Includes funds that invest primarily in real estate.
(7) Includes investment in a group annuity product issued by an insurance company.
(8) Certain investments that were measured at net asset value per share have not been classified in the fair value hierarchy. These amounts are presented to reconcile
to total pension plan assets.
8,116
$ 60,575
At December 31, 2021 and 2020, our pension plans investments were classified under the same fair value measurement hierarchy
(Level 1 through Level 3) described under Note 9, Fair Value of Financial Instruments. The Level 3 investments were recorded
at fair value based on the contract value of annuity products underlying guaranteed deposit accounts, which was calculated using
discounted cash flow models. The contract value of these products represented deposits made to the contract, plus earnings at
guaranteed crediting rates, less withdrawals and fees. Certain investments that were measured at net asset value per share have
not been classified in the fair value hierarchy and are presented in the table above to reconcile to total pension plan assets.
The following table sets forth the summary of the changes in the fair value of Level 3 investments for the years ended
December 31, 2021 and 2020:
Chesapeake Utilities Corporation 2021 Form 10-K Page 97
Notes to the Consolidated Financial Statements
(in thousands)
Balance, beginning of year
Purchases
Transfers in
Disbursements
Investment income
Balance, end of year
Other Postretirement Benefits Plans
For the Year Ended December 31,
2021
2020
$
$
1,019 $
3,160
5,914
(9,587)
(9)
497 $
1,147
3,190
921
(4,290)
51
1,019
We sponsor two defined benefit postretirement health plans: the Chesapeake Utilities Postretirement Plan ("Chesapeake
Postretirement Plan") and the FPU Medical Plan. The following table sets forth the funded status at December 31, 2021 and
2020:
At December 31,
(in thousands)
Change in benefit obligation:
Benefit obligation — beginning of year
$
Interest cost
Plan participants contributions
Actuarial loss (gain)
Benefits paid
Benefit obligation — end of year
Change in plan assets:
Fair value of plan assets — beginning of year
Employer contributions
Plan participants contributions
Benefits paid
Fair value of plan assets — end of year
Reconciliation:
Funded status
Accrued postretirement cost
Assumptions:
Discount rate
Chesapeake
Postretirement Plan
2020
2021
FPU
Medical Plan
2021
2020
$
1,033
22
190
159
(470)
934
—
280
190
(470)
—
$
$
1,100
26
166
(34)
(225)
1,033
—
59
166
(225)
—
1,009
24
29
71
(129)
1,004
—
100
29
(129)
—
1,224
30
37
(181)
(101)
1,009
—
64
37
(101)
—
(934)
(934)
$
(1,033)
(1,033) $
(1,004)
(1,004)
$
(1,009)
(1,009)
$
2.83 %
2.25 %
2.51 %
2.50 %
Chesapeake Utilities Corporation 2021 Form 10-K Page 98
Notes to the Consolidated Financial Statements
Net periodic postretirement benefit costs for 2021, 2020, and 2019 include the following components:
For the Years Ended December 31,
(in thousands)
Components of net periodic
postretirement cost:
Interest cost
Amortization of actuarial loss (gain)
Amortization of prior service cost
Net periodic cost
Amortization of pre-merger regulatory
asset
Total periodic cost
Assumptions
Discount rate
Chesapeake
Postretirement Plan
2020
2021
2019
FPU
Medical Plan
2020
2019
2021
$
22
34
(77)
(21)
—
$
$
26
24
(77)
(27)
$
39
46
(77)
8
—
—
$
(21)
$
(27) $
8
$
24
(9)
—
15
—
15
$
$
30
(19)
—
11
6
$
17
$
48
—
—
48
8
56
2.25 %
3.00 %
4.00 %
2.50 %
3.25 %
4.25 %
The following table presents the amounts not yet reflected in net periodic benefit cost and included in accumulated other
comprehensive loss or as a regulatory asset as of December 31, 2021:
FPU
Pension
Plan
Chesapeake
SERP
Chesapeake
Postretirement
Plan
FPU
Medical
Plan
(in thousands)
Prior service (credit)
Net loss (gain)
Total
Accumulated other comprehensive loss (gain) pre-
tax(1)
Post-merger regulatory asset
Total unrecognized cost
$
$
$
$
— $
17,737
17,737 $
3,370 $
14,367
17,737 $
— $
659
659 $
659 $
—
659 $
(293) $
671
378 $
— $
(114)
(114) $
Total
(293)
18,953
18,660
378 $
—
378 $
(22) $
(92)
(114) $
4,385
14,275
18,660
(1) The total amount of accumulated other comprehensive loss recorded on our consolidated balance sheet as of December 31, 2021 is net of income tax benefits
of $1.1 million.
Pursuant to a Florida PSC order, FPU continues to record as a regulatory asset a portion of the unrecognized pension and
postretirement benefit costs after the merger with Chesapeake Utilities related to its regulated operations, which is included in
the above table as a post-merger regulatory asset. As of December 31, 2021, the pre-merger regulatory asset related to the FPU
Pension and FPU Medical Plan was fully amortized.
Assumptions
The assumptions used for the discount rate to calculate the benefit obligations were based on the interest rates of high-quality
bonds in 2021, considering the expected lives of each of the plans. In determining the average expected return on plan assets for
each applicable plan, various factors, such as historical long-term return experience, investment policy and current and expected
allocation, were considered. Due to the termination of the Chesapeake Pension Plan during the fourth quarter of 2021, different
assumptions regarding discount rate and expected return on plan assets were selected for Chesapeake Utilities' and FPU’s plans.
Since the FPU Pension Plan is frozen with respect to additional years of service and compensation, the rate of assumed
compensation increases is not applicable.
Chesapeake Utilities Corporation 2021 Form 10-K Page 99
Notes to the Consolidated Financial Statements
The health care inflation rate for 2021 used to calculate the benefit obligation is 5 percent for medical and 6 percent for
prescription drugs for the Chesapeake Postretirement Plan; and 5 percent for both medical and prescription drugs for the FPU
Medical Plan.
Estimated Future Benefit Payments
In 2022, we expect to contribute $0.3 million to the FPU Pension Plan and $0.2 million to the Chesapeake SERP. We also expect
to contribute less than $0.1 million to both the Chesapeake Postretirement Plan and FPU Medical Plan, in 2022.
The schedule below shows the estimated future benefit payments for each of the plans previously described:
FPU Pension
Plan(1)
Chesapeake
SERP(2)
Chesapeake
Postretirement
Plan(2)
FPU
Medical
Plan(2)
(in thousands)
2022
2023
2024
2025
2026
Years 2027 through 2031
(1) The pension plan is funded; therefore, benefit payments are expected to be paid out of the plan assets.
(2) Benefit payments are expected to be paid out of our general funds.
3,451 $
3,537 $
3,592 $
3,690 $
3,720 $
18,588 $
$
$
$
$
$
$
151 $
149 $
147 $
160 $
157 $
723 $
73 $
68 $
63 $
59 $
54 $
218 $
71
70
71
70
69
324
Retirement Savings Plan
For the years ended December 31, 2021, 2020 and 2019, we sponsored a 401(k) Retirement Savings Plan. This plan is offered to
all eligible employees who have completed three months of service. We match 100 percent of eligible participants’ pre-tax
contributions to the Retirement Savings Plan up to a maximum of six percent of eligible compensation. The employer matching
contribution is made in cash and is invested based on a participant’s investment directions. In addition, we may make a
discretionary supplemental contribution to participants in the plan, without regard to whether or not they make pre-tax
contributions. Any supplemental employer contribution is generally made in our common stock. With respect to the employer
match and supplemental employer contribution, employees are 100 percent vested after two years of service or upon reaching 55
years of age while still employed by us. New employees who do not make an election to contribute and do not opt out of the
Retirement Savings Plan will be automatically enrolled at a deferral rate of three percent, and the automatic deferral rate will
increase by one percent per year up to a maximum of ten percent. All contributions and matched funds can be invested among
the mutual funds available for investment.
Employer contributions to our Retirement Savings Plan totaled $5.9 million, $5.9 million, and $5.7 million for the years ended
December 31, 2021, 2020 and 2019, respectively. As of December 31, 2021, there were 798,586 shares of our common stock
reserved to fund future contributions to the Retirement Savings Plan.
Non-Qualified Deferred Compensation Plan
Members of our Board of Directors and officers of the Company are eligible to participate in the Non-Qualified Deferred
Compensation Plan. Directors can elect to defer any portion of their cash or stock compensation and officers can defer up to 80
percent of their base compensation, cash bonuses or any amount of their stock bonuses (net of required withholdings). Officers
may receive a matching contribution on their cash compensation deferrals up to six percent of their compensation, provided it
does not duplicate a match they receive in the Retirement Savings Plan. Stock bonuses are not eligible for matching contributions.
Participants are able to elect the payment of deferred compensation to begin on a specified future date or upon separation from
Chesapeake Utilities Corporation 2021 Form 10-K Page 100
Notes to the Consolidated Financial Statements
service. Additionally, participants can elect to receive payments upon the earlier or later of a fixed date or separation from service.
The payments can be made in one lump sum or annual installments for up to 15 years.
All obligations arising under the Non-Qualified Deferred Compensation Plan are payable from our general assets, although we
have established a Rabbi Trust to informally fund the plan. Deferrals of cash compensation may be invested by the participants
in various mutual funds (the same options that are available in the Retirement Savings Plan). The participants are credited with
gains or losses on those investments. Deferred stock compensation may not be diversified. The participants are credited with
dividends on our common stock in the same amount that is received by all other stockholders. Such dividends are reinvested into
our common stock. Assets held in the Rabbi Trust, recorded as Investments on the consolidated balance sheet, had a fair value of
$12.1 million and $10.8 million at December 31, 2021 and 2020, respectively. (See Note 10, Investments, for further details). The
assets of the Rabbi Trust are at all times subject to the claims of our general creditors.
Deferrals of officer base compensation and cash bonuses and directors’ cash retainers are paid in cash. All deferrals of executive
performance shares, which represent deferred stock units, and directors’ stock retainers are paid in shares of our common stock,
except that cash is paid in lieu of fractional shares. The value of our stock held in the Rabbi Trust is classified within the
stockholders’ equity section of the consolidated balance sheets and has been accounted for in a manner similar to treasury stock.
The amounts recorded under the Non-Qualified Deferred Compensation Plan totaled $7.2 million and $5.7 million at
December 31, 2021 and 2020, respectively, which are also shown as a deduction against stockholders' equity in the consolidated
balance sheet.
18. SHARE-BASED COMPENSATION PLANS
Our non-employee directors and key employees have been granted share-based awards through our SICP. We record these share-
based awards as compensation costs over the respective service period for which services are received in exchange for an award
of equity or equity-based compensation. The compensation cost is based primarily on the fair value of the shares awarded, using
the estimated fair value of each share on the date it was granted, and the number of shares to be issued at the end of the service
period. We have 369,099 shares of common stock reserved for issuance under the SICP.
The table below presents the amounts included in net income related to share-based compensation expense for the awards granted
under the SICP for the years ended December 31, 2021, 2020 and 2019:
For the Year Ended December 31,
2020
2019
2021
(in thousands)
Awards to non-employee directors
Awards to key employees
Total compensation expense
Less: tax benefit
Share-based compensation amounts included in net income
$
$
782 $
5,163
5,945
(1,535)
4,410 $
733 $
4,096
4,829
(1,254)
3,575 $
620
3,659
4,279
(1,117)
3,162
Non-employee Directors
Shares granted to non-employee directors are issued in advance of the directors’ service periods and are fully vested as of the
grant date. We record a deferred expense equal to the fair value of the shares issued and amortize the expense equally over a
service period of one year. In May 2021, after the most recent election of directors, each of our non-employee directors received
an annual retainer of 683 shares of common stock under the SICP for service as a director through the 2022 Annual Meeting of
Stockholders; accordingly, 6,830 shares, with a weighted average fair value of $117.11 per share, were issued and vested in 2021.
At December 31, 2021, there was $0.3 million of unrecognized compensation expense related to shares granted to non-employee
directors. This expense will be recognized over the remaining service period ending in May 2022.
Chesapeake Utilities Corporation 2021 Form 10-K Page 101
Notes to the Consolidated Financial Statements
In October 2021, a newly appointed member of the Board of Directors received a pro-rated retainer of 342 shares of common
stock under the SICP to serve as a non-employee director through the 2022 Annual Meeting of Stockholders. The shares awarded
to the non-employee director immediately vested upon issuance in October 2021, had a weighted average fair value of $129.09
per share, and will be expensed over the remaining service period ending on the date of the 2022 Annual Meeting of Stockholders.
In May 2020, after the most recent election of directors, each of our non-employee directors received an annual retainer of 887
shares of common stock under the SICP for board service through the 2021 Annual Meeting of Stockholders; accordingly, 8,870
shares, with a weighted average fair value of $84.47 per share, were issued and vested in 2020.
Our Compensation Committee is authorized to grant our key employees the right to receive awards of shares of our common
stock, contingent upon the achievement of established performance goals and subject to SEC transfer restrictions once awarded.
Our President and CEO has the right to issue awards of shares of our common stock, to other officers of the Company, contingent
upon various performance goals and subject to SEC transfer restrictions.
We currently have several outstanding multi-year performance plans, which are based upon the successful achievement of long-
term goals, growth and financial results and comprise both market-based and performance-based conditions and targets. The fair
value per share, tied to a performance-based condition or target, is equal to the market price per share on the grant date. For the
market-based conditions, we used the Monte Carlo valuation to estimate the fair value of each share granted.
The table below presents the summary of the stock activity for awards to all officers:
Number of
Shares
Weighted Average
Fair Value
Outstanding — December 31, 2019
Granted
Vested
Expired
Outstanding — December 31, 2020
Granted
Vested
Expired
Forfeited (1)
157,817 $
70,014
(35,651)
(5,302)
186,878
69,903
(53,147)
(852)
(5,384)
197,398 $
80.28
91.89
66.48
65.32
87.06
100.76
76.31
74.85
93.39
94.15
Outstanding — December 31, 2021
(1) In conjunction with the retirement of one key employee during 2020, these shares were forfeited for the remainder of the service periods associated with
awards granted during their employment with the Company.
For the year ended December 31, 2021, we granted awards of 69,903 shares of common stock to officers under the SICP, including
awards granted in February 2021 and to key employees appointed in officer positions. The shares granted are multi-year awards
that will vest no later than the three-year service period ending December 31, 2023. All of these stock awards are earned based
upon the successful achievement of long-term financial results, which are comprised of market-based and performance-based
conditions or targets. The fair value of each performance-based condition or target is equal to the market price of our common
stock on the grant date of each award. For the market-based conditions, we used the Monte Carlo valuation to estimate the fair
value of each market-based award granted.
The intrinsic value of these awards was $28.8 million, $20.2 million and $15.1 million in 2021, 2020 and 2019, respectively. At
December 31, 2021, there was $4.1 million of unrecognized compensation cost related to these awards, which is expected to be
recognized through 2023.
In 2021, 2020 and 2019, we withheld shares with a value at least equivalent to the employees’ minimum statutory obligation for
the applicable income and other employment taxes, and remitted the cash to the appropriate taxing authorities with the executives
electing to receive the net shares. The below table presents the number of shares withheld /and amounts remitted to taxing
authorities:
Chesapeake Utilities Corporation 2021 Form 10-K Page 102
Notes to the Consolidated Financial Statements
For the Year Ended December 31,
2020
2021
2019
(amounts except shares, in thousands)
Shares withheld to satisfy tax obligations
Amounts remitted to tax authorities to satisfy obligations
$
14,020
1,478 $
10,319
977 $
7,635
692
Chesapeake Utilities Corporation 2021 Form 10-K Page 103
Notes to the Consolidated Financial Statements
19. RATES AND OTHER REGULATORY ACTIVITIES
Our natural gas and electric distribution operations in Delaware, Maryland and Florida are subject to regulation by their respective
PSC; Eastern Shore, our natural gas transmission subsidiary, is subject to regulation by the FERC; and Peninsula Pipeline and
Aspire Energy Express, our intrastate pipeline subsidiaries, are subject to regulation (excluding cost of service) by the Florida
PSC and Public Utilities Commission of Ohio, respectively.
Delaware
See the discussion below under COVID-19 impact.
Maryland
Strategic Infrastructure Development and Enhancement (“STRIDE”) plan: In March 2021, Elkton Gas filed a strategic
infrastructure development and enhancement plan with the Maryland PSC. The STRIDE plan accelerates Elkton Gas' Aldyl-A
pipeline replacement program as costs of the plan are recovered through a fixed charge rider which is effective for five years.
Under Elkton Gas’ STRIDE plan, the Aldyl-A pipelines will be fully replaced by 2023. In July 2021, Elkton Gas reached a
settlement with the Maryland PSC Staff and the Maryland Office of Public Counsel that approved Elkton Gas’ STRIDE plan.
The STRIDE plan allows for recovery of the associated revenue requirement through a monthly surcharge, which was
implemented effective September 2021.
Florida
West Palm Beach Expansion Project: In August 2019, the Florida PSC approved Peninsula Pipeline’s Transportation Service
Agreement with FPU. Peninsula Pipeline constructed several new interconnection points and pipeline expansions in Palm Beach
County, Florida, which will enable FPU to serve an industrial research park and several new residential developments. Peninsula
Pipeline is now providing transportation service to FPU, increasing reliability and system pressure as well as introducing diversity
in the fuel source for natural gas to serve the increased demand in these areas. Interim services began in the fourth quarter of
2019, and we completed the remainder of the project in phases through the fourth quarter of 2021.
Winter Haven Expansion Project: In May 2021, Peninsula Pipeline filed a petition with the Florida PSC for approval of its
Transportation Service Agreement with CFG for an incremental 6,800 Dts/d of firm service in the Winter Haven, Florida area.
As part of this agreement, Peninsula Pipeline will construct a new interconnect with FGT and a new regulator station for CFG.
CFG will use the additional firm service to support new incremental load due to growth, including providing service to a new can
manufacturing facility, as well as provide reliability and operational benefits to CFG’s existing distribution system in the area. In
connection with Peninsula Pipeline’s new regulator station, CFG is also extending its distribution system to connect to the new
station. The Transportation Service Agreement was approved by the Florida PSC in September 2021. Construction commenced
in February 2021 and the expected in-service date is March 2022.
Beachside Pipeline Extension: In June 2021, Peninsula Pipeline and Florida City Gas entered into a Transportation Service
Agreement for an incremental 10,176 Dts/d of firm service in Indian River County, Florida, to support Florida City Gas’ growth
along the Indian River's barrier island. As part of this agreement, Peninsula Pipeline will construct 11 miles of pipeline from its
existing pipeline in the Sebastian, Florida area, which will travel east under the Intercoastal Waterway ("ICW") and southward
on the barrier island. As required by Peninsula Pipeline’s tariff and Florida Statutes, Peninsula Pipeline filed the required company
and customer affidavits with the Florida PSC in June 2021. Construction also commenced in June 2021 and the expected in-
service date is December 2022.
Eastern Shore
Del-Mar Energy Pathway Project: In December 2019, the FERC issued an order approving the construction of the Del-Mar
Energy Pathway project. The order approved the construction and operation of new facilities that provides an additional 14,300
Dts/d of firm service to four customers. This includes six miles of pipeline looping in Delaware; 13 miles of new mainline
extension in Sussex County, Delaware and Wicomico and Somerset Counties in Maryland; and new pressure control and delivery
stations in these counties. The benefits of this project include: (i) additional natural gas transmission pipeline infrastructure in
eastern Sussex County, Delaware, and (ii) extension of Eastern Shore’s pipeline system, for the first time, into Somerset County,
Chesapeake Utilities Corporation 2021 Form 10-K Page 104
Notes to the Consolidated Financial Statements
Maryland. The project is now fully in service as the construction of the Somerset County, Maryland expansion was completed in
the third quarter of 2021.
Capital Cost Surcharge: In June 2021, Eastern Shore submitted a filing with the FERC regarding a capital cost surcharge to
recover capital costs associated with two mandated highway relocate projects that required the replacement of existing Eastern
Shore facilities. The capital cost surcharge is an approved item in the settlement of Eastern Shore’s last rate case. In conjunction
with the filing of this surcharge, pursuant to the settlement agreement, a cumulative adjustment to the existing surcharge to reflect
additional depreciation was included in this filing. The FERC issued an order approving the surcharge as filed on July 7, 2021.
The combined revised surcharge became effective July 15, 2021.
COVID-19 Impact
In March 2020, the CDC declared a national emergency due to the rapidly growing outbreak of COVID-19. In response to this
declaration and the rapid spread of COVID-19 within the United States, federal, state and local governments throughout the
country imposed varying degrees of restrictions on social and commercial activity to promote social distancing to slow the spread
of the illness. These restrictions significantly impacted economic conditions in the United States in 2020 and continued through
the fourth quarter of 2021. Chesapeake Utilities is considered an “essential business,” which has allowed us to continue
operational activities and construction projects with appropriate safety precautions and personal protective equipment, while
being mindful of the social distancing restrictions that were in place.
In response to the COVID-19 pandemic and related restrictions, we experienced reduced consumption of energy largely in the
commercial and industrial sectors, higher bad debt expenses and incremental expenses associated with COVID-19, including
expenditures associated with personal protective equipment and premium pay for field personnel. The additional operating
expenses we incurred support the ongoing delivery of our essential services during these unprecedented times.
In 2021, restrictions were gradually lifted as vaccines became widely available in the United States. The state of emergency in
Florida was terminated in May 2021 followed by Delaware and Maryland in July 2021. However, in light of the winter surge of
COVID-19 cases, in January 2022, another state of emergency was declared in Delaware and Maryland. Considering the
prevalence of new variants of COVID-19, we continue to operate under our pandemic response plan, monitor developments
affecting employees, customers, suppliers, stockholders and take all precautions warranted to operate safely and to comply with
the CDC and the Occupational Safety and Health Administration, with a goal of minimizing further exposure for our employees,
customers and the communities.
In April 2020, the Maryland PSC issued an order that authorized utilities to establish a regulatory asset to record prudently
incurred incremental costs related to COVID-19, beginning on March 16, 2020. The Maryland PSC found that the creation of a
regulatory asset for COVID-19 related expenses will facilitate the recovery of those costs prudently incurred to serve customers
during the COVID-19 pandemic, and that the deferral of such costs is appropriate because the current catastrophic health
emergency is outside the control of the utility and is a non-recurring event. The Maryland PSC reviewed and issued guidance
regarding the distribution of funds and the manner in which the utilities will allocate the funds to customers with eligible
arrearages. Chesapeake Utilities – Maryland Division, Sandpiper Energy, and Elkton Gas received $0.3 million in the third
quarter of 2021 to credit the accounts of those customers experiencing financial hardship in becoming current on their past due
balances.
In May 2020, the Delaware PSC issued an order that authorized Delaware utilities to establish a regulatory asset to record COVID-
19 related incremental costs incurred to ensure customers have essential utility services, for the period beginning on March 24,
2020 and ending 30 days after the state of emergency ends. The state of emergency was lifted July 12, 2021. However, in light of
the winter surge of COVID-19 cases, a new state of emergency was declared in January 2022. The creation of the regulatory asset
for COVID-19 related costs offers utilities the ability to seek recovery of those costs. Funds to assist with individual customer
Chesapeake Utilities Corporation 2021 Form 10-K Page 105
Notes to the Consolidated Financial Statements
arrearages have become available through the Delaware State Housing Authority. We are working to ensure that customers know
how to seek this support and then apply it to their overdue utility bills.
The Company’s Florida regulated business units reached a settlement with the Florida OPC in June 2021 related to incremental
expenses incurred due to COVID-19. The settlement allows the units to establish a regulatory asset in a total amount of
$2.1 million as of June 30, 2021. This amount includes COVID-19 related incremental expenses for bad debt write-offs, personnel
protective equipment, cleaning and business information services for remote work. Our Florida regulated business units will
amortize the regulatory asset over two years and recover it through the Purchased Gas Adjustment and Swing Service mechanisms
for the natural gas business units and through the Fuel Purchased Power Cost Recovery clause for the electric division. This
settlement agreement was approved by the Florida PSC on July 8, 2021 and the final order was issued on July 22, 2021.
In the fourth quarter of 2020, we began recording regulatory assets based on the net incremental expense resulting from the
COVID-19 pandemic for our natural gas distribution and electric business units as authorized by the Delaware, Maryland and
Florida PSCs. As of December 31, 2021 and 2020, our total COVID-19 regulatory asset balance was $2.3 million and
$1.9 million, respectively.
Summary TCJA Table
Customer rates for our regulated business were adjusted as approved by the regulators, prior to 2020 except for Elkton Gas, which
implemented a one-time bill credit in May 2020. The following table summarized the regulatory liabilities related to accumulated
deferred taxes ("ADIT") associated with TCJA for our regulated businesses as of December 31, 2021 and 2020:
Operation and Regulatory
Jurisdiction
Eastern Shore (FERC)
Delaware Division (Delaware
PSC)
Maryland Division (Maryland
PSC)
Sandpiper Energy (Maryland
PSC)
Chesapeake Florida Gas
Division/Central Florida Gas
(Florida PSC)
FPU Natural Gas (excludes Fort
Meade and Indiantown) (Florida
PSC)
FPU Fort Meade and Indiantown
Divisions
FPU Electric (Florida PSC)
Elkton Gas (Maryland PSC)
Amount (in thousands)
December 31, 2021
December 31, 2020
$34,190
$12,591
$3,840
$3,656
$8,032
$34,190
$12,728
$3,970
$3,713
$8,184
$19,189
$19,257
Status
Will be addressed in Eastern Shore's next rate case
filing.
PSC approved amortization of ADIT in January
2019.
PSC approved amortization of ADIT in May 2018.
PSC approved amortization of ADIT in May 2018.
PSC issued order authorizing amortization and
retention of net ADIT liability by the Company in
February 2019.
Same treatment on a net basis as Chesapeake Florida
Gas Division (above).
$271
$5,237
$1,091
$309
$6,694
$1,124
Same treatment on a net basis as Chesapeake
Florida Gas Division (above).
In January 2019, PSC issued order approving
amortization of ADIT through purchased power
cost recovery, storm reserve and rates.
PSC approved amortization of ADIT in March
2018.
Chesapeake Utilities Corporation 2021 Form 10-K Page 106
Notes to the Consolidated Financial Statements
Regulatory Assets and Liabilities
At December 31, 2021 and 2020, our regulated utility operations recorded the following regulatory assets and liabilities included
in our consolidated balance sheets. These assets and liabilities will be recognized as revenues and expenses in future periods as
they are reflected in customers’ rates.
(in thousands)
Regulatory Assets
Under-recovered purchased fuel and conservation cost recovery (1)
Under-recovered GRIP revenue (2)
Deferred postretirement benefits (3)
Deferred conversion and development costs (1)
Environmental regulatory assets and expenditures (4)
Acquisition adjustment (5)
Loss on reacquired debt (6)
Deferred costs associated with COVID-19 (7)
Deferred storm costs (8)
Other
Total Regulatory Assets
Regulatory Liabilities
Self-insurance (9)
Over-recovered purchased fuel and conservation cost recovery (1)
Over-recovered GRIP revenue (2)
Storm reserve (9)
Accrued asset removal cost (10)
Deferred income taxes due to rate change (11)
Interest related to storm recovery (8)
Other
Total Regulatory Liabilities
As of December 31,
2021
2020
$
$
$
$
9,199 $
2,101
16,749
23,383
1,258
27,182
721
2,289
36,004
5,081
123,967 $
563 $
1,073
11
2,829
47,887
88,804
2,146
1,487
144,800 $
2,078
278
17,716
23,054
1,743
28,756
795
1,925
44,320
3,927
124,592
533
4,422
338
2,673
45,315
90,845
3,353
1,541
149,020
Chesapeake Utilities Corporation 2021 Form 10-K Page 107
Notes to the Consolidated Financial Statements
(1) We are allowed to recover the asset or are required to pay the liability in rates. We do not earn an overall rate of return on these assets.
(2) The Florida PSC allowed us to recover through a surcharge, capital and other program-related-costs, inclusive of an appropriate return on investment, associated
with accelerating the replacement of qualifying distribution mains and services (defined as any material other than coated steel or plastic) in FPU’s natural gas
distribution, Fort Meade division and Chesapeake Utilities’ Central Florida Gas division. We are allowed to recover the asset or are required to pay the liability
in rates related to GRIP.
(3) The Florida PSC allowed FPU to treat as a regulatory asset the portion of the unrecognized costs pursuant to ASC Topic 715, Compensation - Retirement
Benefits, related to its regulated operations. This balance also includes the portion of pension settlement expense associated with the termination of the Chesapeake
Pension Plan pursuant to an order from the FERC and the respective PSCs that allowed us to defer Eastern Shore, Delaware and Maryland Divisions' portion.
See Note 17, Employee Benefit Plans, for additional information.
(4) All of our environmental expenditures incurred to date and our current estimate of future environmental expenditures have been approved by various PSCs for
recovery. See Note 20, Environmental Commitments and Contingencies, for additional information on our environmental contingencies.
(5) We are allowed to include the premiums paid in various natural gas utility acquisitions in Florida in our rate bases and recover them over a specific time period
pursuant to the Florida PSC approvals. We paid $34.2 million of the premium in 2009, including a gross up for income tax, because it is not tax deductible, and
$0.7 million of the premium paid by FPU in 2010.
(6) Gains and losses resulting from the reacquisition of long-term debt are amortized over future periods as adjustments to interest expense in accordance with
established regulatory practice.
(7) We deferred as regulatory assets the net incremental expense impact associated with the net expense impact of COVID-19 as authorized by the stated PSCs.
(8) The Florida PSC authorized us to recover regulatory assets (including interest) associated with the recovery of Hurricanes Michael and Dorian storm costs
which will be amortized between 6 and 10 years. Recovery of these costs includes a component of an overall return on capital additions and regulatory assets.
(9) We have storm reserves in our Florida regulated energy operations and self-insurance for our regulated energy operations that allow us to collect through rates
amounts to be used against general claims, storm restoration costs and other losses as they are incurred.
(10) See Note 1, Summary of Significant Accounting Policies, for additional information on our asset removal cost policies.
(11) We recorded a regulatory liability for our regulated businesses related to the revaluation of accumulated deferred tax assets/liabilities as a result of the TCJA.
The liability will be amortized over a period between 5 to 80 years based on the remaining life of the associated property. Based upon the regulatory proceedings,
we will pass back the respective portion of the excess accumulated deferred taxes to rate payers. See Note 12, Income Taxes, for additional information.
20. ENVIRONMENTAL COMMITMENTS AND CONTINGENCIES
We are subject to federal, state and local laws and regulations governing environmental quality and pollution control. These laws
and regulations require us to remove or remediate, at current and former operating sites, the effect on the environment of the
disposal or release of specified substances.
MGP Sites
We have participated in the investigation, assessment or remediation of, and have exposures at, seven former MGP sites. We have
received approval for recovery of clean-up costs in rates for sites located in Salisbury, Maryland; Seaford, Delaware; and Winter
Haven, Key West, Pensacola, Sanford and West Palm Beach, Florida.
As of December 31, 2021 and 2020, we had approximately $5.2 million and $5.9 million, respectively, in environmental
liabilities, related to the former MGP sites. As of December 31, 2021 and 2020, we have cumulative regulatory assets of $1.3
million and $1.7 million, respectively, in regulatory assets for future recovery of environmental costs for customers. Specific to
FPU's four MGP sites in Key West, Pensacola, Sanford and West Palm Beach, FPU has approval to recover, from insurance and
from customers through rates, up to $14.0 million of its environmental costs related to its MGP sites. As of December 31, 2021
and 2020, we have recovered approximately $12.9 million and $12.4 million, respectively, leaving approximately $1.1 million
and $1.6 million, respectively, in regulatory assets for future recovery of environmental costs from FPU’s customers.
Environmental liabilities for our MGP sites are recorded on an undiscounted basis based on the estimate of future costs provided
by independent consultants. We continue to expect that all costs related to environmental remediation and related activities,
including any potential future remediation costs for which we do not currently have approval for regulatory recovery, will be
recoverable from customers through rates.
Remediation is ongoing for the MGP's in Winter Haven and Key West in Florida and in Seaford, Delaware and the remaining
clean-up costs are estimated to be between $0.3 million to $0.9 million for these three sites. The Environmental Protection
Agency has approved a "site-wide ready for anticipated use" status for the Sanford, Florida MGP site, which is the final step
before delisting a site. The remaining remediation expenses for the Sanford MGP site are immaterial.
The following is a summary of our remediation status and estimated costs to implement clean-up of our West Palm Beach Florida
site:
Chesapeake Utilities Corporation 2021 Form 10-K Page 108
Notes to the Consolidated Financial Statements
Status
Remedial actions approved by the Florida Department of
Environmental Protection have been implemented on the east
parcel of the site. Similar remedial actions have been initiated
on the site's west parcel, and construction of active remedial
systems are expected be completed in 2022.
Estimated Cost to Clean Up
(Expect to Recover through Rates)
Between $3.3 million to $14.2 million, including costs
associated with the relocation of FPU’s operations at this
site, and any potential costs associated with future
redevelopment of the properties.
21. OTHER COMMITMENTS AND CONTINGENCIES
Natural Gas, Electric and Propane Supply
In March 2020, our Delmarva Peninsula natural gas distribution operations entered into asset management agreements with a
third party to manage their natural gas transportation and storage capacity. The agreements were effective as of April 1, 2020 and
expire in March 2023.
FPU natural gas distribution operations and Eight Flags have separate asset management agreements with Emera Energy Services,
Inc. to manage their natural gas transportation capacity. These agreements are for a 10-year term that commenced in November
2020 and expire in October 2030.
Chesapeake Utilities' Florida Division has firm transportation service contracts with FGT and Gulfstream. Pursuant to a capacity
release program approved by the Florida PSC, all of the capacity under these agreements has been released to various third parties.
Under the terms of these capacity release agreements, Chesapeake Utilities is contingently liable to FGT and Gulfstream should
any party, that acquired the capacity through release, fail to pay the capacity charge. To date, Chesapeake Utilities has not been
required to make a payment resulting from this contingency.
FPU’s electric supply contracts require FPU to maintain an acceptable standard of creditworthiness based on specific financial
ratios. FPU’s agreement with Florida Power & Light Company requires FPU to meet or exceed a debt service coverage ratio of
1.25 times based on the results of the prior 12 months. If FPU fails to meet this ratio, it must provide an irrevocable letter of credit
or pay all amounts outstanding under the agreement within five business days. FPU’s electric supply agreement with Gulf Power
requires FPU to meet the following ratios based on the average of the prior six quarters: (a) funds from operations interest
coverage ratio (minimum of 2 times), and (b) total debt to total capital (maximum of 65 percent). If FPU fails to meet the
requirements, it has to provide the supplier a written explanation of actions taken, or proposed to be taken, to become compliant.
Failure to comply with the ratios specified in the Gulf Power agreement could also result in FPU having to provide an irrevocable
letter of credit. As of December 31, 2021, FPU was in compliance with all of the requirements of its fuel supply contracts.
Eight Flags provides electricity and steam generation services through its CHP plant located on Amelia Island, Florida. In June
2016, Eight Flags began selling power generated from the CHP plant to FPU pursuant to a 20-year power purchase agreement
for distribution to our electric customers. In July 2016, Eight Flags also started selling steam pursuant to a separate 20-year
contract, to the landowner on which the CHP plant is located. The CHP plant is powered by natural gas transported by FPU
through its distribution system and Peninsula Pipeline through its intrastate pipeline.
The total purchase obligations for natural gas, electric and propane supplies are as follows:
Year
(in thousands)
Purchase Obligations
2022
2023-2024
2025-2026
Beyond 2026
Total
$
89,557 $
82,412 $
70,114 $
174,203 $
416,286
Corporate Guarantees
The Board of Directors has authorized us to issue corporate guarantees securing obligations of our subsidiaries and to obtain
letters of credit securing our subsidiaries' obligations. The maximum authorized liability under such guarantees and letters of
Chesapeake Utilities Corporation 2021 Form 10-K Page 109
Notes to the Consolidated Financial Statements
credit as of December 31, 2021 was $20.0 million. The aggregate amount guaranteed at December 31, 2021 was approximately
$13.1 million with the guarantees expiring on various dates through December 1, 2022.
As of December 31, 2021, we have issued letters of credit totaling approximately $5.3 million related to the electric transmission
services for FPU's electric division, the firm transportation service agreement between TETLP and our Delaware and Maryland
divisions, the capacity agreement between NEXUS and Aspire, and our current and previous primary insurance carriers. These
letters of credit have various expiration dates through October 25, 2022. There have been no draws on these letters of credit as of
December 31, 2021. We do not anticipate that the counterparties will draw upon these letters of credit, and we expect that they
will be renewed to the extent necessary in the future.
Chesapeake Utilities Corporation 2021 Form 10-K Page 110
ITEM 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL DISCLOSURE.
None.
ITEM 9A. CONTROLS AND PROCEDURES.
EVALUATION OF DISCLOSURE CONTROLS AND PROCEDURES
Our Chief Executive Officer and Chief Financial Officer, with the participation of other Company officials, have evaluated our
“disclosure controls and procedures” (as such term is defined under Rule 13a-15(e) and Rule 15d-15(e) promulgated under the
Securities Exchange Act of 1934, as amended) as of December 31, 2021. Based upon their evaluation, our Chief Executive Officer
and Chief Financial Officer concluded that our disclosure controls and procedures were effective as of December 31, 2021.
CHANGE IN INTERNAL CONTROLS
In response to the COVID-19 pandemic and social distancing restrictions that have been established in our service territories, our
current pandemic response plan includes having office staff work remotely to promote social distancing in efforts to reduce the
ongoing spread of COVID-19. During the quarter ended December 31, 2021, our pandemic response plan did not result in a
change in the design or operations of our internal controls over financial reporting that has materially affected, or is reasonably
likely to materially affect, our internal control over financial reporting. There has been no change in internal control over financial
reporting (as such term is defined in Exchange Act Rule 13a-15(f)) that occurred during the quarter ended December 31, 2021,
that materially affected, or is reasonably likely to materially affect, internal control over financial reporting.
CEO AND CFO CERTIFICATIONS
Our Chief Executive Officer and Chief Financial Officer have filed with the SEC the certifications required by Section 302 of the
Sarbanes-Oxley Act of 2002 as Exhibits 31.1 and 31.2 to our Annual Report on Form 10-K for the fiscal year ended December 31,
2021. In addition, in May 28, 2021, our Chief Executive Officer certified to the NYSE that he was not aware of any violation by
us of the NYSE corporate governance listing standards.
MANAGEMENT'S REPORT ON INTERNAL CONTROL OVER FINANCIAL REPORTING
Management is responsible for establishing and maintaining adequate internal control over financial reporting, as such term is
defined in Rule 13a-15(f) of the Exchange Act. A company’s internal control over financial reporting is a process designed to
provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for
external purposes in accordance with GAAP. A company’s internal control over financial reporting includes those policies and
procedures that: (i) pertain to the maintenance of records which in reasonable detail, accurately and fairly reflect the transactions
and dispositions of the assets of the company; (ii) provide reasonable assurance that transactions are recorded as necessary to
permit preparation of financial statements in accordance with GAAP and that receipts and expenditures of the company are being
made only in accordance with authorizations of management and directors of the company; and (iii) provide reasonable assurance
regarding prevention or timely detection of unauthorized acquisition, use, or disposition of the company’s assets that could have
a material effect on the financial statements.
Under the supervision and with the participation of management, including the Chief Executive Officer and Chief Financial
Officer, our management conducted an evaluation of the effectiveness of its internal control over financial reporting based on the
criteria established in an updated report entitled “Internal Control - Integrated Framework,” issued in May 2013 by the Committee
of Sponsoring Organizations of the Treadway Commission. Because of its inherent limitations, internal control over financial
reporting may not prevent or detect misstatements. Also, projections of any evaluation of effectiveness to future periods are
subject to the risk that controls may become inadequate because of changes in conditions, or that the degree of compliance with
the policies or procedures may deteriorate.
Our management has evaluated and concluded that our internal control over financial reporting was effective as of December 31,
2021.
Chesapeake Utilities Corporation 2021 Form 10-K Page 111
Our independent registered public accounting firm, Baker Tilly US, LLP, has audited the effectiveness of our internal control over
financial reporting as of December 31, 2021, as stated in its report which appears under Part II, Item 8. Financial Statements and
Supplementary Data.
ITEM 9B. OTHER INFORMATION.
None.
PART III
ITEM 10. DIRECTORS, EXECUTIVE OFFICERS OF THE REGISTRANT AND CORPORATE GOVERNANCE.
We have adopted a Code of Ethics that applies to our Principal Executive Officer, President, Principal Financial Officer, Chief
Accounting Officer, Corporate Controller, Assistant Treasurer, and persons performing similar functions, which is a “code of
ethics” as defined by applicable rules of the SEC. This Code of Ethics is publicly available on our website at https://chpk.com.
If we make any amendments to this code other than technical, administrative or other non-substantive amendments, or grant any
waivers, including implicit waivers, from a provision of this code to our Principal Executive Officer, President, Principal
Financial Officer, Chief Accounting Officer or Corporate Controller, we intend to disclose the nature of the amendment or
waiver, its effective date and to whom it applies by posting such information on our website at the address and location specified
above.
The remaining information required by this Item is incorporated herein by reference to the sections of our Proxy Statement
captioned “Election of Directors (Proposal 1),” “Governance Trends and Director Education," "Corporate Governance
Practices,” “Board of Directors and its Committees” and “Delinquent Section 16(a) Reports.”
ITEM 11. EXECUTIVE COMPENSATION.
The information required by this Item is incorporated herein by reference to the sections of our Proxy Statement captioned
“Director Compensation,” “Executive Compensation” and “Compensation Discussion and Analysis".
ITEM 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED STOCKHOLDER
MATTERS.
The information required by this Item is incorporated herein by reference to the sections of our Proxy Statement captioned
“Security Ownership of Certain Beneficial Owners and Management” and "Equity Compensation Plan Information."
ITEM 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE.
The information required by this Item is incorporated herein by reference to the section of our Proxy Statement captioned
“Corporate Governance Practices” and "Director Independence."
ITEM 14. PRINCIPAL ACCOUNTING FEES AND SERVICES.
The information required by this Item is incorporated herein by reference to the portion of the Proxy Statement captioned “Fees
and Services of Independent Registered Public Accounting Firm." The Company's independent registered public accounting
firm is Baker Tilly, LLP, PCAOB ID: (23)
Chesapeake Utilities Corporation 2021 Form 10-K Page 112
PART IV
ITEM 15. EXHIBITS, FINANCIAL STATEMENT SCHEDULES.
The following documents are filed as part of this Annual Report:
(a)(1) All of the financial statements, reports and notes to the financial statements included in Item 8 of Part II of this
Annual Report on Form 10-K.
(a)(2) Schedule II—Valuation and Qualifying Accounts.
(a)(3) The Exhibits below.
• Exhibit 1.1
• Exhibit 3.1
• Exhibit 3.2
• Exhibit 3.3
• Exhibit 3.4
• Exhibit 3.5
• Exhibit 3.6
• Exhibit 3.7
• Exhibit 4.1
• Exhibit 4.2
Equity Distribution Agreement, dated August 17, 2020, by and between Chesapeake
Utilities Corporation and each of RBC Capital Markets, LLC, BofA Securities, Inc., Wells
Fargo Securities, LLC, Janney Montgomery Scott LLC, Guggenheim Securities, LLC,
Maxim Group LLC, Sidoti & Company, LLC, and Siebert Williams Shank & Co., LLC is
incorporated herein by reference to Exhibit 1.1 of our Current Report on Form 8-K, filed
August 17, 2020, File No. 001-11590.
Amended and Restated Certificate of Incorporation of Chesapeake Utilities Corporation is
incorporated herein by reference to Exhibit 3.1 of our Quarterly Report on Form 10-Q for
the period ended June 30, 2010, File No. 001-11590.
Amended and Restated Bylaws of Chesapeake Utilities Corporation, effective December 4,
2012, are incorporated herein by reference to Exhibit 3 of our Current Report on Form 8-K,
filed December 7, 2012, File No. 001-11590.
First Amendment to the Amended and Restated Bylaws of Chesapeake Utilities Corporation,
effective December 3, 2014, is incorporated herein by reference to Exhibit 3.3 of our Annual
Report on Form 10-K for the year ended December 31, 2014, File No. 001-11590.
Second Amendment to the Amended and Restated Bylaws of Chesapeake Utilities
Corporation, effective November 2, 2016, is incorporated herein by reference to Exhibit 3.3
of our Quarterly Report on Form 10-Q for the quarter ended September 30, 2016, File No.
001-11590.
Certificate of Amendment to the Amended and Restated Certificate of Incorporation of
Chesapeake Utilities Corporation, is incorporated herein by reference to Exhibit 3.1 of our
Current Report on Form 8-K, filed May 9, 2017, File No. 001-11590.
Certificate of Elimination of Series A Participating Cumulative Preferred Stock of
Chesapeake Utilities Corporation, is incorporated herein by reference to Exhibit 3.6 to our
Annual Report on Form 10-K for the year ended December 31, 2017, File No. 001-11590.
Third Amendment to the Amended and Restated Bylaws of Chesapeake Utilities
Corporation, effective May 8, 2019, is incorporated by reference to Exhibit 3.1 of our
Current Report on Form 8-K, filed May 14, 2019, File No. 001-11590.
Note Agreement dated October 31, 2008, among Chesapeake Utilities Corporation, as
issuer, General American Life Insurance Company and New England Life Insurance
Company, relating to the private placement of Chesapeake Utilities Corporation's 5.93%
Senior Notes due 2023.†
Note Agreement dated June 29, 2010, among Chesapeake Utilities Corporation, as issuer,
Metropolitan Life Insurance Company and New England Life Insurance Company, relating
to the private placement of Chesapeake Utilities Corporation’s 5.68% Senior Notes due
2026 and Chesapeake Utilities Corporation’s 6.43% Senior Notes due 2028.†
Chesapeake Utilities Corporation 2021 Form 10-K Page 113
• Exhibit 4.3
• Exhibit 4.4
• Exhibit 4.5
• Exhibit 4.6
• Exhibit 4.7
• Exhibit 4.8
• Exhibit 4.9
• Exhibit 4.10
• Exhibit 10.1*
• Exhibit 10.2*
• Exhibit 10.3*
• Exhibit 10.4*
Note Agreement dated September 5, 2013, among Chesapeake Utilities Corporation, as
issuer, and certain note holders, relating to the private placement of Chesapeake Utilities
Corporation’s 3.73% Senior Notes due 2028 and Chesapeake Utilities Corporation’s 3.88%
Senior Notes due 2029.†
Private Shelf Agreement dated October 8, 2015, between Chesapeake Utilities Corporation,
as issuer, and Prudential Investment Management Inc., relating to the private placement of
Chesapeake Utilities Corporation's 3.25% Senior Notes due 2032, 3.98% Senior Notes due
2039, 3.0% Senior Notes due 2035, and the sale of other Chesapeake Utilities Corporation
unsecured Senior Notes from time to time, is incorporated herein by reference to Exhibit 4.1
of our Quarterly Report on Form 10-Q for the period ended September 30, 2015, File No.
001-11590.
First Amendment to Private Shelf Agreement dated September 14, 2018, between
Chesapeake Utilities Corporation, as issuer, and PGIM, Inc. (formerly known as Prudential
Investment Management, Inc.), and other purchasers that may become party thereto. †
Master Note Agreement dated March 2, 2017, among Chesapeake Utilities Corporation, as
issuer, NYL Investors LLC, and other certain note holders that may become party thereto
from time to time relating to the private placement of Chesapeake Utilities Corporation’s
3.48% Senior Notes due 2038 and Chesapeake Utilities Corporation’s 3.58% Senior Notes
due 2038, and Chesapeake Utilities Corporation’s 2.96% Senior Notes due 2035. †
Note Purchase Agreement, dated August 25, 2021, by and among Chesapeake Utilities
Corporation, MetLife Insurance K.K., Thrivent Financial For Lutherans, CMFG Life
Insurance Company, and American Memorial Life Insurance Company relating to the
placement of Chesapeake Utilities Corporation’s 2.49% Senior Notes due 2037. †
Private Shelf Agreement, dated March 2, 2017, by and among Chesapeake Utilities
Corporation, Metropolitan Life Insurance Company, and MetLife Investment Management,
LLC, relating to the private placement of Chesapeake Utilities Corporation’s 2.95% Senior
Notes due 2042.†
First Amendment to Private Shelf Agreement, dated May 14, 2020, by and among
Chesapeake Utilities Corporation, Metropolitan Life Insurance Company, and MetLife
Investment Management, LLC. †
Description of Securities Registered Under Section 12 of the Securities Exchange Act of
1934, as amended, is filed herewith.
Chesapeake Utilities Corporation Cash Bonus Incentive Plan, effective January 1, 2015, is
incorporated herein by reference to our Proxy Statement dated March 31, 2015, in
connection with our Annual Meeting held on May 6, 2015, File No. 001-11590.
Chesapeake Utilities Corporation 2013 Stock and Incentive Compensation Plan, effective
May 2, 2013 is incorporated herein by reference to our Proxy Statement dated March 29,
2013 in connection with our Annual Meeting held on May 2, 2013, File No. 001-11590.
Non-Qualified Deferred Compensation Plan, effective January 1, 2014, is incorporated
herein by reference to Exhibit 10.8 of our Annual Report on Form 10-K for the year ended
December 31, 2013, File No. 001-11590.
Chesapeake Utilities Corporation Supplemental Executive Retirement Plan, as amended and
restated effective January 1, 2009, is incorporated herein by reference to Exhibit 10.27 of
our Annual Report on Form 10-K for the year ended December 31, 2008, File No. 001-
11590.
Chesapeake Utilities Corporation 2021 Form 10-K Page 114
• Exhibit 10.5*
• Exhibit 10.6
• Exhibit 10.7
• Exhibit 10.8
• Exhibit 10.9*
• Exhibit 10.10*
• Exhibit 10.11
• Exhibit 10.12
• Exhibit 10.13*
• Exhibit 10.14
First Amendment to the Chesapeake Utilities Corporation Supplemental Executive
Retirement Plan as amended and restated effective January 1, 2009, is incorporated herein
by reference to Exhibit 10.30 of our Annual Report on Form 10-K for the year ended
December 31, 2010, File No. 001-11590.
Revolving Credit Agreement dated October 8, 2015, between Chesapeake Utilities
Corporation and PNC Bank, National Association, Bank of America, N.A., Citizens Bank
N.A., Royal Bank of Canada and Wells Fargo Bank, National Association as lenders, is
incorporated herein by reference to Exhibit 10.1 of our Quarterly Report on Form 10-Q for
the period ended September 30, 2015, File No. 001-11590.
First Amendment dated February 25, 2016 to the Revolving Credit Agreement dated
October 8, 2015, between Chesapeake Utilities Corporation and PNC Bank, National
Association, Bank of America, N.A., Citizens Bank N.A., Royal Bank of Canada and Wells
Fargo Bank, National Association as lenders, is incorporated herein by reference to Exhibit
10.24 of our Annual Report on Form 10-K for the year ended December 31, 2015, File No.
001-11590.
Credit Agreement, dated November 28, 2017, by and between Chesapeake Utilities
Corporation and Branch Banking and Trust Company is incorporated herein by reference to
Exhibit 10.20 of our Annual Report on Form 10-K for the year ended December 31, 2018,
File No. 001-11590.
Form of Performance Share Agreement, effective February 25, 2019 for the period January
1, 2019 to December 31, 2021, pursuant to Chesapeake Utilities Corporation 2013 Stock
and Incentive Compensation Plan by and between Chesapeake Utilities Corporation and
Jeffry M. Householder is incorporated herein by reference to Exhibit 10.24 of our Annual
Report on Form 10-K for the year ended December 31, 2018, File No. 001-11590.
Executive Employment Agreement dated February 25, 2019, between Chesapeake Utilities
Corporation and Jeffry M. Householder, is incorporated herein by reference to Exhibit 10.25
of our Annual Report on Form 10-K for the year ended December 31, 2018, File No. 001-
11590.
Term Note dated January 31, 2019 issued by Chesapeake Utilities Corporation in favor of
Branch Banking & Trust Company is incorporated herein by reference to Exhibit 10.1 of
our Quarterly Report on Form 10-Q for the quarter ended March 30, 2019, File No. 001-
11590.
Term Loan Credit Agreement, dated January 31, 2019, by and between Chesapeake Utilities
Corporation and Branch Banking and Trust Company is incorporated herein by reference to
Exhibit 10.2 of our Quarterly Report on Form 10-Q for the quarter ended March 30, 2019,
File No. 001-11590.
Executive Retirement Agreement dated October 9, 2019, between Chesapeake Utilities
Corporation and Stephen C. Thompson is incorporated herein by reference to Exhibit 10.1
of our Quarterly Report on Form 10-Q for the quarter ended September 30, 2019, File No.
001-11590
Note Purchase Agreement dated November 19, 2019, between Chesapeake Utilities
Corporation, The Guardian Life Insurance Company of America, The Guardian Insurance
& Annuity Company, Inc., Berkshire Life Insurance Company of America, Thrivent
Financial for Lutherans, United of Omaha Life Insurance Company, and CMFG Life
Insurance Company is incorporated herein by reference to our Current Report on Form 8-K
filed on November 20, 2019, File No. 001-11590.
Chesapeake Utilities Corporation 2021 Form 10-K Page 115
• Exhibit 10.15*
• Exhibit 10.16*
• Exhibit 10.17*
• Exhibit 10.18*
• Exhibit 10.19
• Exhibit 10.20
• Exhibit 10.21
• Exhibit 10.22
• Exhibit 10.23
• Exhibit 10.24
• Exhibit 10.25
Form of Performance Share Agreement, effective December 3, 2019 for the period 2019 to
2021, pursuant to Chesapeake Utilities Corporation 2013 Stock and Incentive Compensation
Plan by and between Chesapeake Utilities Corporation and each of Jeffry M. Householder,
Beth W. Cooper, James F. Moriarty and Kevin Webber is incorporated herein by reference
to Exhibit 10.26 to our Annual Report on Form 10-K for the year ended December 31, 2019,
File No. 001-11590.
Executive Employment Agreement dated December 4, 2019, between Chesapeake Utilities
Corporation and Kevin Webber, is filed incorporated herein by reference to Exhibit 10.27 to
our Annual Report on Form 10-K for the year ended December 31, 2019, File No. 001-
11590.
Form of Performance Share Agreement, effective February 25, 2020 for the period 2020 to
2022, pursuant to Chesapeake Utilities Corporation 2013 Stock and Incentive Compensation
Plan by and between Chesapeake Utilities Corporation and each of Jeffry M. Householder,
Beth W. Cooper, James F. Moriarty and Kevin Webber is incorporated herein by reference
to Exhibit 10.28 to our Annual Report on Form 10-K for the year ended December 31, 2019,
File No. 001-11590.
Form of Performance Share Agreement, effective February 24, 2021, for the period 2021 to
2023, pursuant to the Chesapeake Utilities Corporation 2013 Stock and Incentive
Compensation Plan by and between Chesapeake Utilities Corporation and each of Jeffry M.
Householder, Beth W. Cooper, James F. Moriarty, Kevin Webber, and Jeffrey S. Sylvester is
filed herewith.
Loan Agreement dated April 24, 2020, between Chesapeake Utilities Corporation and PNC
Bank, National Association is incorporated herein by reference to Exhibit 10.3 to our
Quarterly Report on Form 10-Q for the quarter ended March 31, 2020, File No. 001-11590.
Loan Agreement dated April 27, 2020, between Chesapeake Utilities Corporation and Bank
of America, N.A. is incorporated herein by reference to Exhibit 10.4 to our Quarterly Report
on Form 10-Q for the quarter ended March 31, 2020, File No. 001-11590.
Revolving Line of Credit Note dated April 24, 2020 issued by Chesapeake Utilities
Corporation in favor of PNC Bank, National Association is incorporated herein by reference
to Exhibit 10.5 to our Quarterly Report on Form 10-Q for the quarter ended March 31, 2020,
File No. 001-11590.
Promissory Note dated April 22, 2020, issued by Chesapeake Utilities Corporation and in
favor of Bank of America, N.A. is incorporated herein by reference to Exhibit 10.6 to our
Quarterly Report on Form 10-Q for the quarter ended March 31, 2020, File No. 001-11590.
Credit Agreement dated May 29, 2020, between Chesapeake Utilities Corporation and
Citizens Bank National Association is incorporated herein by reference to Exhibit 10.1 to
our Quarterly Report on Form 10-Q for the quarter ended June 30, 2020, File No. 001-
11590.
Loan Agreement dated May 6, 2020 between Chesapeake Utilities Corporation and Royal
bank of Canada is incorporated herein by reference to Exhibit 10.2 to our Quarterly Report
on Form 10-Q for the quarter ended June 30, 2020, File No. 001-11590.
Form of Revolving Loan Note in favor of Citizens Bank National Association is
incorporated herein by reference to Exhibit 10.3 to our Quarterly Report on Form 10-Q for
the quarter ended June 30, 2020, File No. 001-11590.
Chesapeake Utilities Corporation 2021 Form 10-K Page 116
• Exhibit 10.26
• Exhibit 10.27
• Exhibit 10.28
• Exhibit 10.29*
• Exhibit 10.30*
• Exhibit 10.31*
• Exhibit 10.32*
• Exhibit 10.33*
• Exhibit 10.34*
• Exhibit 21
Form of Revolving Credit Note in favor of Royal Bank of Canada is incorporated herein by
reference to Exhibit 10.4 to our Quarterly Report on Form 10-Q for the quarter ended June
30, 2020, File No. 001-11590.
Credit Agreement, dated September 30, 2020, by and between Chesapeake Utilities
Corporation, PNC Bank, National Association, and several other financial institutions
named therein is incorporated herein by reference to Exhibit 10.1 to our Quarterly Report
on Form 10-Q for the quarter ended September 30, 2020, File No. 001-11590.
Amended and Restated Credit Agreement, dated August 12, 2021, by and between
Chesapeake Utilities Corporation, PNC Bank, National Association, and several other
financial institutions named therein is incorporated herein by reference to Exhibit 10.1 to
our Quarterly Report on Form 10-Q for the quarter ended September 30, 2021, File No. 001-
11590
Executive Employment Agreement, dated December 16, 2021, by and between Chesapeake
Utilities Corporation and Jeffrey S. Sylvester is incorporated by reference to Exhibit 10.1 to
our Current Report on Form 8-K filed on December 20, 2021, File No. 001-11590
Executive Employment Agreement, dated December 16, 2021, by and between Chesapeake
Utilities Corporation and Jeffry M. Householder is incorporated by reference to Exhibit 10.2
to our Current Report on Form 8-K filed on December 20, 2021, File No. 001-11590
Executive Employment Agreement, dated December 16, 2021, by and between Chesapeake
Utilities Corporation and Beth W. Cooper is incorporated by reference to Exhibit 10.3 to our
Current Report on Form 8-K filed on December 20, 2021, File No. 001-11590
Executive Employment Agreement, dated December 16, 2021, by and between Chesapeake
Utilities Corporation and James F. Moriarty is incorporated by reference to Exhibit 10.4 to
our Current Report on Form 8-K filed on December 20, 2021, File No. 001-11590
Executive Employment Agreement, dated December 16, 2021, by and between Chesapeake
Utilities Corporation and Kevin J. Webber is incorporated by reference to Exhibit 10.5 to
our Current Report on Form 8-K filed on December 20, 2021, File No. 001-11590
Form of Performance Share Agreement, effective February 23, 2022, for the period 2022 to
2024, pursuant to the Chesapeake Utilities Corporation 2013 Stock and Incentive
Compensation Plan by and between Chesapeake Utilities Corporation and each of Jeffry M.
Householder, Beth W. Cooper, James F. Moriarty, Kevin J. Webber, and Jeffrey S. Sylvester
is filed herewith.
Subsidiaries of the Registrant is filed herewith.
• Exhibit 23.1
Consent of Independent Registered Public Accounting Firm is filed herewith.
• Exhibit 31.1
• Exhibit 31.2
• Exhibit 32.1
• Exhibit 32.2
Certificate of Chief Executive Officer of Chesapeake Utilities Corporation pursuant to
Exchange Act Rule 13a-14(a) and 15d – 14(a), is filed herewith.
Certificate of Chief Financial Officer of Chesapeake Utilities Corporation pursuant to
Exchange Act Rule 13a-14(a) and 15d – 14(a), is filed herewith.
Certificate of Chief Executive Officer of Chesapeake Utilities Corporation pursuant to 18
U.S.C. Section 1350, is filed herewith.
Certificate of Chief Financial Officer of Chesapeake Utilities Corporation pursuant to 18
U.S.C. Section 1350, is filed herewith.
• Exhibit 101.INS XBRL Instance Document is filed herewith.
• Exhibit 101.SCH XBRL Taxonomy Extension Schema Document is filed herewith.
• Exhibit 101.CAL XBRL Taxonomy Extension Calculation Linkbase Document is filed herewith.
• Exhibit 101.DEF XBRL Taxonomy Extension Definition Linkbase Document is filed herewith.
• Exhibit 101.LAB XBRL Taxonomy Extension Label Linkbase Document is filed herewith.
Chesapeake Utilities Corporation 2021 Form 10-K Page 117
• Exhibit 101.PRE XBRL Taxonomy Extension Presentation Linkbase Document is filed herewith.
• Exhibit 104
Cover Page Interactive Data File - formatted in Inline XBRL and contained in Exhibit 101.
*
†
Management contract or compensatory plan or agreement.
These agreements have not been filed herewith pursuant to Item 601(b)(4)(v) of Regulation S-K under the Securities
Act of 1933, as amended. We hereby agree to furnish copies to the SEC upon request.
Chesapeake Utilities Corporation 2021 Form 10-K Page 118
ITEM 16. FORM 10-K SUMMARY.
None.
Pursuant to the requirements of Section 13 or 15 (d) of the Securities Exchange Act of 1934, Chesapeake Utilities Corporation
has duly caused this report to be signed on its behalf by the undersigned, thereunto duly authorized.
SIGNATURES
CHESAPEAKE UTILITIES CORPORATION
By:
/s/ JEFFRY M. HOUSEHOLDER
Jeffry M. Householder
President, Chief Executive Officer and Director
February 23, 2022
Pursuant to the requirements of the Securities Exchange Act of 1934, this report has been signed below by the following
persons on behalf of the registrant and in the capacities and on the dates indicated.
/s/ JEFFRY M. HOUSEHOLDER
Jeffry M. Householder
President, Chief Executive Officer and Director
February 23, 2022
/S/ BETH W. COOPER
Beth W. Cooper, Executive Vice President,
Chief Financial Officer,
and Assistant Corporate Secretary
(Principal Financial and Accounting Officer)
February 23, 2022
/S/ JOHN R. SCHIMKAITIS
John R. Schimkaitis
Chair of the Board and Director
February 23, 2022
/S/ LISA G. BISACCIA
Lisa G. Bisaccia, Director
February 23, 2022
/S/ THOMAS J. BRESNAN
Thomas J. Bresnan, Director
February 23, 2022
/S/ RONALD G. FORSYTHE, JR.
Dr. Ronald G. Forsythe, Jr., Director
February 23, 2022
/S/ THOMAS P. HILL, JR.
Thomas P. Hill, Jr., Director
February 23, 2022
/S/ DENNIS S. HUDSON, III
Dennis S. Hudson, III, Director
February 23, 2022
/S/ LILA A. JABER
Lila A. Jaber, Director
February 23, 2022
/S/ PAUL L. MADDOCK, JR.
Paul L. Maddock, Jr., Director
February 23, 2022
/S/ CALVERT A. MORGAN, JR.
Calvert A. Morgan, Jr., Director
February 23, 2022
/S/ DIANNA F. MORGAN
Dianna F. Morgan, Director
February 23, 2022
Chesapeake Utilities Corporation 2021 Form 10-K Page 119
Chesapeake Utilities Corporation and Subsidiaries
Schedule II
Valuation and Qualifying Accounts
For the Year Ended December 31,
(In thousands)
Reserve Deducted From Related Assets
Reserve for Uncollectible Accounts
2021
2020
2019
$
$
$
(1) Recoveries and other allowance adjustments
(2) Uncollectible accounts charged off.
Additions
Balance at
Beginning of
Year
Charged to
Income
Other
Accounts (1)
Deductions (2)
Balance at End
of Year
4,785 $
1,337 $
1,058 $
134 $
3,827 $
1,392 $
(125) $
613 $
278 $
(1,653) $
(992) $
(1,391) $
3,141
4,785
1,337
Chesapeake Utilities Corporation 2020 Form 10-K Page 120
Corporate Information
CORPORATE OFFICE
Chesapeake Utilities Corporation
500 Energy Lane
Dover, DE 19901
Telephone: 302.734.6799
Website: www.chpk.com
TRANSFER AGENT AND REGISTRAR
Computershare Trust Company, N.A.
c/o Chesapeake Utilities Corporation
P.O. Box 505000
Louisville, KY 40233-5000
Toll-Free Telephone
(in US and Canada): 877.498.8865
Outside of US and Canada: 781.575.2879
Website: www.computershare.com/investor
DIVIDEND REINVESTMENT
AND DIRECT STOCK PURCHASE PLAN
The Dividend Reinvestment and Direct Stock
Purchase Plan provides flexible investment
options for those who wish to invest in the
Company. Common stock holders can have
their dividends automatically reinvested to
purchase additional shares directly through
the Plan and/or send in additional optional
cash investments at any time to increase their
holdings. New investors can purchase shares
directly through the Plan. For more information,
please contact the Company’s transfer agent
(Computershare) as stated above.
ANALYST INFORMATION
Beth W. Cooper
Executive Vice President and
Chief Financial Officer
Telephone: 302.734.6799
bcooper@chpk.com
Alex Whitelam
Head of Investor Relations
Telephone: 215.872.2507
awhitelam@chpk.com
COMMON STOCK AND
DIVIDEND INFORMATION
NYSE: CPK
Chesapeake Utilities Corporation’s common
stock is traded on the New York Stock Exchange
under the symbol CPK.
QUARTER
ENDED 2021
March 31
June 30
September 30
December 31
PRICE RANGE
LOW
$99.64
$113.49
$117.41
$120.77
HIGH
$121.04
$124.94
$133.40
$146.07
CLOSE
$116.08
$120.33
$120.05
$145.81
QUARTER
ENDED 2020
March 31
June 30
September 30
December 31
PRICE RANGE
LOW
$69.47
$76.55
$72.89
$82.43
HIGH
$101.29
$95.00
$89.10
$111.40
CLOSE
$85.71
$84.00
$84.30
$108.21
DIVIDENDS
DECLARED
PER SHARE*
$0.4400
$0.4800
$0.4800
$0.4800
DIVIDENDS
DECLARED
PER SHARE*
$0.4050
$0.4400
$0.4400
$0.4400
*Declaration of dividends is at the discretion of the Board of Directors.
Dividends in 2021 and 2020 were paid quarterly.
PUBLIC INFORMATION AND SEC FILINGS
Our latest news and filings with the Securities
and Exchange Commission (SEC), including
Forms 10-K, 10-Q and 8-K are available to
view or request a printed copy, free of charge,
at our website, www.chpk.com.
If you wish to request a printed copy of any
of the Company’s publications by mail, please
send your written request to Investor
Relations at the Corporate Office.
INVESTOR RELATIONS/
SHAREHOLDER SERVICES
Heidi W. Watkins
Shareholder Services Manager
Telephone (toll free): 888.742.5275
hwatkins@chpk.com
Sustain Growth. Make a Difference. Lead the Way. Our Board of Directors
The Board of Directors of Chesapeake Utilities Corporation provides guidance and
insight for the entire Company, leveraging their prior diverse experiences and leadership
expertise to strengthen our business and long-term strategic focus.
John R. Schimkaitis
DIRECTOR SINCE 1996
Chair of the Board,
Retired President and Chief
Executive Officer,
Chesapeake Utilities Corporation
Lisa G. Bisaccia
DIRECTOR SINCE 2021
Retired Executive Vice President and
Chief Human Resources Officer of
CVS Health,
Providence, Rhode Island
Thomas J. Bresnan
DIRECTOR SINCE 2001
Owner and President,
Denver Accounting Services,
Denver, Colorado
Ronald G. Forsythe, Jr., Ph.D.
DIRECTOR SINCE 2014
Thomas P. Hill, Jr.
DIRECTOR SINCE 2006
Chief Executive Officer,
Qlarant Corporation,
Easton, Maryland
Retired Vice President of
Finance and Chief Financial Officer,
Exelon Energy Delivery Company,
Philadelphia, Pennsylvania
Jeffry M. Householder
DIRECTOR SINCE 2019
President and Chief Executive
Officer, Chesapeake Utilities
Corporation
2021 Annual Report Chesapeake Utilities Corporation The Marlin Gas Services tractor transports pictured here are fueled by compressed natural gas (CNG), reducing greenhouse gas emissions by up to 20% compared to diesel fuel.Marlin Gas Services, a subsidiary of Chesapeake Utilities Corporation, operates a fleet of compressed natural gas (CNG), liquefied natural gas (LNG), renewable natural gas (RNG) and hydrogen transport trailers designed to provide virtual pipeline and temporary fueling solutions.Paul L. Maddock, Jr.DIRECTOR SINCE 2009 Chief Executive Officer and Manager, Palamad, LLC, Palm Beach, FloridaCalvert A. Morgan, Jr.DIRECTOR SINCE 2000Retired Director and Former Special Advisor, WSFS Financial Corporation, and Retired Director and Former Vice Chair, Wilmington Savings Fund Society (WSFS Bank), Wilmington, Delaware; Retired Chair, President & Chief Executive Officer, PNC Bank, Wilmington, DelawareDianna F. MorganDIRECTOR SINCE 2008Former Senior Vice President, Walt Disney World Co., Orlando, Florida; Past Chair of the Board of Trustees, University of Florida, Gainesville, FloridaDennis S. Hudson, IIIDIRECTOR SINCE 2009Former Executive Chair of the Board, and Chief Executive Officer, Seacoast Banking Corporation of Florida & Seacoast National Bank, Stuart, Florida COMPENSATION COMMITTEEDianna F. Morgan—CHAIRLisa G. BisacciaRonald G. Forsythe, Jr., Ph.D.Dennis S. Hudson, IIICalvert A. Morgan, Jr. CORPORATE GOVERNANCE COMMITTEECalvert A. Morgan, Jr.—CHAIRLila A. Jaber, Esq.Paul L. Maddock, Jr.Dianna F. Morgan INVESTMENT COMMITTEEJeffry M. Householder—CHAIRThomas J. BresnanThomas P. Hill, Jr.Calvert A. Morgan, Jr.John R. SchimkaitisAUDIT COMMITTEE Thomas J. Bresnan—CHAIRRonald G. Forsythe, Jr., Ph.D.Thomas P. Hill, Jr.Dennis S. Hudson, IIILila A. Jaber, Esq. DIRECTOR SINCE 2020President, Jaber Group Inc., Tallahassee, FloridaSustain Growth. Make a Difference. Lead the Way. Our Commitment:
Sustain Growth.
Make a Difference.
Lead the Way.
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500 Energy Lane, Dover, Delaware 19901 USA | chpk.com
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