Bringing
Natural Resources
to Life
2021 ANNUAL REPORT
Our Operations
NACCO Industries, Inc.® brings natural resources to life by delivering aggregates, minerals,
reliable fuels and environmental solutions through its robust portfolio of NACCO Natural
Resources businesses. The Company operates under three business segments: Coal Mining,
North American Mining and Minerals Management. The Coal Mining segment operates
surface coal mines for power generation companies and an activated carbon producer. The
North American Mining segment is a trusted mining partner for producers of aggregates,
lithium and other minerals. The Minerals Management segment, which includes the
Catapult Mineral Partners business, acquires and promotes the development of mineral
interests. In addition, Mitigation Resources of North America® provides stream and wetland
mitigation solutions.
NACCO Industries®
Above left: We operate in a culture committed to safety excellence. We
expect employees to work safely and look out for each other, regardless of
business or location. Above right: We invest in our employees by offering
a competitive market-based, total-rewards package that includes a
combination of salaries and wages and a benefits package that promotes
employee physical, mental, and financial well-being.
Contents
About the Company . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1
Selected Financial and Operating Data . . . . . . . . . . . . . . . . . . . . . . . 2
Letter to Stockholders . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4
Corporate Responsibility . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9
Form 10-K . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13
Directors and Leadership . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .140
Corporate Information . . . . . . . . . . . . . . . . . . . . . . Inside Back Cover
About the Cover
We have a strong legacy of environmental stewardship and a commitment
to being a good corporate citizen. The cover of this Annual Report highlights
the boat ramp at Red Hills Mine’s R1 Lake in Ackerman, Mississippi, which was
originally a sedimentation pond when operations began at the mine. The lake
is now a managed trophy bass lake open to employees and guests.
At left: The Tobaksákola mitigation site located in the Upper Big Black Basin
in Webster County, Mississippi, includes approximately 45,000 linear feet of
stream construction and 57.5 acres of bottomland hardwood enhancement.
Restoration of the site took place over a two-year period.
1
Selected Financial and
Operating Data
NACCO Industries, Inc. and Subsidiaries
2021
2020(1)
Year Ended December 31
2019
(In thousands, except per share data)
2018
2017(1)
Operating Statement Data:
Revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Operating profit . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
$ 191,846
$ 55,410
$ 128,432
13,448
$
$ 140,990
38,820
$
$ 135,375
43,624
$
$ 104,778
$ 32,814
Income from continuing operations . . . . . . . . . . . . . . . .
Discontinued operations, net-of-tax(2) . . . . . . . . . . . . . .
Net income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
$ 48,125
–
$ 48,125
Basic Earnings per Share:
Income from continuing operations . . . . . . . . . . . . . . .
Discontinued operations, net-of-tax(2). . . . . . . . . . . . . .
Basic earnings per share . . . . . . . . . . . . . . . . . . . . . . . . . . .
Diluted Earnings per Share:
Income from continuing operations . . . . . . . . . . . . . . . .
Discontinued operations, net-of-tax(2) . . . . . . . . . . . . . .
Diluted earnings per share . . . . . . . . . . . . . . . . . . . . . . . . .
$
$
$
$
6.73
–
6.73
6.69
–
6.69
Per Share and Share Data:
Cash dividends . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Market value at December 31(3) . . . . . . . . . . . . . . . . . . . .
Stockholders’ equity at December 31 . . . . . . . . . . . . . .
Actual shares outstanding at December 31 . . . . . . . . .
Basic weighted average shares outstanding . . . . . . . .
Diluted weighted average shares outstanding . . . . . .
$ 0.7850
36.29
$
49.02
$
7,183
7,146
7,190
$
$
$
$
$
$
$
$
$
14,793
–
14,793
2.11
–
2.11
2.10
–
2.10
0.7675
26.30
42.59
7,058
7,026
7,057
$
$
$
$
$
$
$
$
$
39,632
–
39,632
5.68
–
5.68
5.66
–
5.66
0.7350
46.83
41.54
6,966
6,974
7,007
$
$
$
$
$
$
$
$
$
34,785
–
34,785
$ 28,463
1,874
$ 30,337
5.02
–
5.02
5.00
–
5.00
$
$
$
$
4.17
0.27
4.44
4.14
0.27
4.41
0.6600
33.90
36.22
6,921
6,924
6,960
$ 0.9775
37.65
$
32.03
$
6,852
6,830
6,873
(1) During 2020 and 2017, the Company recorded non-cash impairment charges of $8.4 million and $1.0 million, respectively.
(2) On September 29, 2017, the Company spun off its housewares business. The results of operations of the housewares business are reflected as discontinued
operations in the table above.
(3) The 2017 values reflect the effect of the spin-off of the housewares business as a separate public company.
2
2021
2020(1)
Year Ended December 31
2019
(In thousands, except employee data)
2018
2017(1)
Balance Sheet Data at December 31:
Cash . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Total assets(3) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Long-term debt . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Stockholders’ equity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Cash Flow Data:
Provided by (used for) operating activities(4) . . . . . . . .
Used for investing activities(4) . . . . . . . . . . . . . . . . . . . . .
Consolidated Cash Flow before
financing activities (4)(5) . . . . . . . . . . . . . . . . . . . . . . . . . .
$ 86,005
$ 507,220
$ 18,183
$ 352,116
88,450
$
$ 476,179
$
24,353
$ 300,624
$ 122,892
$ 444,773
$
17,148
$ 289,392
85,257
$
$ 376,991
$
6,367
$ 250,704
$ 101,600
$ 389,552
$ 42,021
$ 219,448
$ 74,875
$ (44,147)
$
$
(2,486)
(45,984)
$
$
52,784
(20,262)
$
$
54,622
(18,387)
$ 41,305
(15,005)
$
$ 30,728
$
(48,470)
$ 32,522
$ 36,235
$ 26,300
Provided by (used for) financing activities(4) . . . . . . . .
$ (33,173)
$
14,028
$
5,113
$
(52,578)
$
(2,306)
Other Data:
Total employees at December 31(6) . . . . . . . . . . . . . . . . .
1,600
2,000
2,400
2,400
2,300
(4) Includes both continuing operations and discontinued operations for 2017.
(5) Cash Flow before financing activities is equal to net cash provided by (used for) operating activities less net cash used for investing activities.
(6) Includes employees from the unconsolidated mines for all years presented.
2021
2020(1)
Year Ended December 31
2019
(In thousands)
2018
2017(1)
Calculation of Adjusted EBITDA from
continuing operations(7)
Net income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Discontinued operations, net of tax . . . . . . . . . . . . . . . .
Long-lived asset impairment charges(1) . . . . . . . . . . . .
Contract termination settlement . . . . . . . . . . . . . . . . . .
Income tax provision (benefit) . . . . . . . . . . . . . . . . . . . . .
Interest expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Interest income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Depreciation, depletion and amortization expense . .
Adjusted EBITDA from continuing operations(7) . . . . .
$ 48,125
–
–
(10,333)
8,725
1,719
(449)
23,085
$ 70,872
$
$
14,793
–
8,359
–
(535)
1,354
(1,200)
18,114
40,885
$
$
39,632
–
–
–
3,767
872
(3,616)
16,240
56,895
$
$
34,785
–
–
–
7,378
1,998
(865)
14,683
57,979
$ 30,337
(1,874)
982
–
639
3,440
(222)
12,767
$ 46,069
(7) Adjusted EBITDA from continuing operations is provided solely as a supplemental disclosure with respect to operating results. Adjusted EBITDA from continuing
operations does not represent net income, as defined by U.S. GAAP and should not be considered as a substitute for net income, or as an indicator of operating
performance. NACCO defines Adjusted EBITDA from continuing operations as income from continuing operations before long-lived asset impairment charges,
contract termination settlements, and income taxes, plus interest (income) expense and depreciation, depletion and amortization expense. Adjusted EBITDA
from continuing operations is not a measurement under U.S. GAAP and is not necessarily comparable with similarly titled measures of other companies.
3
NACCO Industries®
To Our Stockholders
During 2021, we delivered a number of
successes as we executed our plans for
growth and diversification while protect-
ing our core coal business. Our businesses
delivered strong results in 2021, gener-
ating operating profit and net income
significantly higher than in 2020. Our coal
operations and oil and gas businesses
both delivered substantial operating profit.
Our aggregates and minerals mining and
environmental banking businesses grew
with seven new projects across Arkansas,
Indiana, Florida, Mississippi, Tennessee and
Texas. As a result, we ended 2021 with a
significantly expanded geographic foot-
print and greater diversification across our
collection of natural resource businesses.
Our team put in tremendous effort to
deliver significant achievements in 2021,
most notably the transaction announced
between Rainbow Energy and Great River
Energy under which Coal Creek Station, one
of North Dakota’s largest and most efficient
power plants, will continue operations. Our
Falkirk Mine is the sole supplier of lignite
to the Coal Creek Station power plant. The
purchase of Coal Creek Station by Rainbow
Energy preserves a valuable asset while
maintaining hundreds of good-paying jobs
that support the state and surrounding
communities. The transaction is expected
to close in the second quarter of 2022. We
look forward to working with Rainbow
Energy to provide competitive and reliable
power to consumers.
We also had a number of successes with
our Grow and Diversify strategy. During
2021, North American Mining expanded
its geographic footprint as it entered into
three new contract mining services agree-
ments at quarries in Indiana, Texas and
Arkansas with two of the larger producers
of aggregates in the United States. North
American Mining also signed a 15-year
dragline services mining contract with a
new customer in Florida. We have begun
the process to relocate and commission a
large dragline that will significantly increase
production capacity at this quarry. While
this contract contributed only modestly
to 2021 results, this project aligns with our
long-term focus and is expected to contrib-
ute more significantly to North American
Mining’s results once the larger dragline is
commissioned in the second half of 2022.
Our Minerals Management business
expanded and diversified in 2021 as our
team at Catapult Mineral Partners acquired
mineral reserves that added to our growing
Permian basin assets and acquired assets
in the Eagle Ford shale in Texas. Also,
Mitigation Resources of North America
launched several new projects, including
its first public works contract related to a
new reservoir in North Texas.
We launched a major rebranding cam-
paign in 2021 that better fits the changing
profile of the Company. NACCO’s portfolio
of natural-resource related businesses now
operates under the umbrella of NACCO
Natural Resources. This new branding
creates a unified identity and underscores
our commitment to all of our businesses,
while focusing on the execution of our
two key strategies – Protect the Core and
Grow and Diversify. The new branding
provides each business with its own unique
identity that can be linked back to the
NACCO legacy brand, and allows us to
talk more clearly about our Company and
what we do. We have created new websites
for each business, new business-specific
logos that are shown throughout this
Annual Report, and a new tagline, “Bringing
Natural Resources to Life,” which reflects
the growing breadth and diversity of our
portfolio of businesses.
The principles our Company was
founded on more than 100 years ago are
the same ones that lead us today: serve
others, develop solutions, always do what’s
right, and treat everyone with dignity and
respect. Our culture defines who we are
today and encourages us to strive for more.
We have a strong history of embracing
new technologies and pursuing new
markets, while never losing sight of why
we are here.
Our new tagline,
“Bringing Natural
Resources to Life,”
reflects the growing
breadth and diversity
of our portfolio
of businesses
Our legacy is rooted in our North American Coal business. Below: A Wirtgen 4200 Surface Miner loads a CAT 789 Mining Truck with lignite at the Red Hills Mine
in Ackerman, Mississippi.
4
NACCO Industries®
Our legacy is rooted in our North
American Coal business, where we partner
with customers as service providers to
create integrated, efficient and cost-
effective contract coal mining services
for mine-mouth power generators. We
recognize that the coal mining industry
faces increasing political and regulatory
challenges, but we believe the use of
coal as a fuel source for electricity in
the United States will continue for the
foreseeable future. Consumers want,
and need, dependable power for their
homes and businesses. Reliable baseload
power from coal, nuclear and natural
gas power plants operate on demand,
providing grid stability and dependable
power for consumers. Wind and solar
farms do not provide the same level of
dependable generation, or grid stability,
that consumers require. In a world with
increasing geopolitical tensions, national
security and energy security will be
increasingly intertwined.
Core strategy is a relentless focus on
managing coal production costs and
maximizing efficiencies and operating
capacity. These efforts improve the
competitiveness of customers with man-
agement fee contracts. These activities
benefit both customers and us, as fuel
cost is a significant driver of power plant
dispatch which, in turn, drives demand
for coal by our customers.
The structure of our North American
Coal contracts eliminates our exposure
to spot coal market price fluctuations.
However, fluctuations in natural gas
prices and the availability of renewable
generation, particularly wind, can
contribute to changes in power plant
dispatch and customer demand for
coal. The significant increase in natural
gas prices during 2021 contributed to
an increase in customer power plant
dispatch and coal deliveries and resulted
in strong operating results in our Coal
Mining segment.
We work diligently to support our
During 2021, our contract mining
customers so they can continue to
produce reliable and affordable energy.
A key component of our Protect the
agreement to operate the Navajo
Mine in New Mexico was terminated.
The Navajo Transitional Energy
5
We enjoy high retention among our employees,
with our most tenured employee celebrating
45 years with the Company in 2021. Whether
working with reclamation at Sabine Mine in
Hallsville, Texas (top left) or braving the North
Dakota weather (top right), our employees benefit
from experienced employee mentors and training
programs. Here, we also see North American
Mining employees in Texas, a Mississippi Lignite
Mining Company employee at Red Hills Mine,
and a dragline operator at Sabine Mine (bottom
three photos).
NACCO Industries®
Company (“NTEC”) assumed control
and responsibility for operation and all
reclamation at the Navajo Mine when it
purchased our former subsidiary, Bisti Fuels
Company. We received a $10.3 million
contract termination fee from NTEC as
required under the agreement. While we
are disappointed to lose an operation, we
are proud of the work we accomplished
since we took over operation of the mine in
2017, including celebrating over four years
without a lost-time accident and making
significant progress on mine reclamation.
The transition to NTEC went smoothly,
and NTEC conveyed its appreciation for
our performance as contract miner at the
Navajo Mine.
While the development of new mines to
supply newly built coal-fired power plants
remains unlikely, growth at North American
Coal could come through the assumption
of operations at existing mines. We will
approach any such opportunity cautiously,
and we anticipate that we would leverage
our low capital/low risk management fee
contract structure for any such project.
Our North American Mining business
leverages our core mining expertise,
which we’ve developed over the last 100-
plus years. Today, we are a trusted and
efficient mining partner for producers of
aggregates, lithium and other minerals,
and we provide a wide range of mining
services that extend far beyond our
historical dragline-oriented model. North
American Mining is well equipped to grow
by providing highly customized solutions
to meet specific customer needs, including
mine development, all aspects of mining
operations, and land reclamation and
remediation services.
North American Mining continues to
work with Lithium Americas to develop
the Thacker Pass Project, in northern
Nevada, on the largest known lithium
resource in the United States, providing
mine design and consulting services as
this project moves through the permitting
process. As construction and operations
begin, North American Mining will provide
comprehensive mining services, with
responsibility for all operational aspects
of the lithium mine under a long-term
management fee contract.
North American Mining’s 2021 financial
results did not meet our expectations, in
part due to costs related to opportunisti-
cally hiring additional experts to bolster its
already strong maintenance and opera-
tional capabilities. North American Mining
is focused on long-term growth by expand-
ing operations with existing customers as
well as new customers and has a strong
pipeline of potential new projects. We
believe that North American Mining can
grow to become a substantial contributor
to operating profit, delivering unlevered
after-tax returns on invested capital in the
mid-teens as this business model matures
and achieves significant scale.
The Minerals Management business
derives income from royalty-based leases
under which lessees make payments to
us based on their production and sale
With more than 100 years of expertise in all aspects of operating surface coal mines, we are leveraging
this experience in our North American Mining and Mitigation Resources of North America businesses.
Above right: North American Mining employees in Florida. Right: The Five Forks Mine in Louisiana.
Below: A Mitigation Resources of North America employee at a Mississippi mitigation site.
NACCO Industries®
Above left: A heavy-equipment operator in Louisiana. Above: The Catapult Mineral Partners team uses
a disciplined approach to target a balance of potential acquisitions that will generate stable cash flow.
of natural gas, oil, natural gas liquids
and coal. We are delivering growth and
diversification by selectively acquiring
additional high-quality mineral and royalty
interests. This business will benefit from
the continued development of its owned
mineral properties without additional
capital investment, as development costs
are borne entirely by third-party producers
who lease the minerals. We believe this
business model can deliver higher average
operating margins over the life of a reserve
than traditional oil and gas companies that
bear the cost of exploration, production
and/or development.
Catapult Mineral Partners, the Company’s
business unit focused on managing and
expanding our portfolio of oil and gas
mineral and royalty interests, has devel-
oped a strong network to source and
secure new acquisitions. During 2021,
Catapult acquired mineral and royalty
interests totaling approximately $5 million,
building on acquisitions of approximately
$14 million in 2020. Total oil and gas min-
eral and royalty interests include approx-
imately 128,000 gross acres and 60,000
net royalty acres as of December 31, 2021,
primarily in the Appalachia, Permian and
Eagle Ford basins. Our goal is to construct a
diversified portfolio of high-quality oil and
natural gas mineral and royalty interests
in the United States that deliver near-term
cash flow yields and long-term growth.
The Catapult management team uses
a disciplined approach to target potential
acquisitions that align with our strategy
Our goal is to construct
a diversified portfolio
of high-quality U.S. oil
and natural gas mineral
and royalty interests
and objectives. Acquisitions may contain
active wells, new wells anticipated to
come online within one to two years of
investment, areas with forecasted future
development within five years after
acquisition and existing producing wells
further along the decline curve that will
generate stable cash flow. In addition, our
acquisitions target an extended geographic
footprint to diversify across multiple basins
with a preliminary focus on the more oil-
rich Permian basin and a secondary focus
on other diversifying basins to increase
regional exposure.
Our Minerals Management business has
been a strong contributor to operating
profit in recent years, as the 2020 and 2021
acquisitions added to our legacy reserves,
while increasing natural gas and oil prices
helped drive strong financial performance.
Future investments are expected to be
accretive, but each investment’s contribu-
tion to near-term earnings is dependent
on the characteristics of that investment,
including the size and type of interests
acquired and the stage and timing of
mineral development. Profits could also
7
At left: Employees from Sabine Mining Company
and Mitigation Resources of North America tour a
reclamation area. Above: North American Mining
employees at a site in Florida.
to Protect the Core and Grow and Diversify
as we maintain our long-term perspective.
Strategic growth and diversification will
generate cash that can be re-invested to
strengthen and expand our businesses.
We take a long-term view of our business,
just as we believe in building long-term
customer relationships. We also remain
focused on creating long-term shareholder
value rather than on quarterly earnings
or short-term stock price movement. As
a result, incentive compensation for our
senior business leaders is paid in part with
restricted NACCO stock, with three- to
ten-year restrictions on sale, because we
believe this fosters good, long-term-ori-
ented decision making. Additionally, in all
of our business endeavors, our employees
maintain the highest levels of customer
service and operational excellence, with an
unwavering focus on safety, environmental
stewardship and people.
I want to thank our employees for their
many contributions to our success and for
continuing to be trusted partners for our
customers and in the communities where
we work. I would also like to thank our
customers and vendors, as well as NACCO’s
long-term stockholders, for their continuing
support. We are passionately committed to
working hard and doing what’s right as we
bring America’s natural resources to life.
J.C. Butler, Jr.
President and Chief Executive Officer
vary due to commodity price changes.
Major global shifts in oil and natural
gas production, and changes in global
natural gas and oil markets, could result
in sustained higher prices for natural gas
and oil, although the duration and extent
of price movements is nearly impossible to
predict. Overall, we believe this business
can continue to be a strong contributor to
operating profit, delivering unlevered after-
tax returns on invested capital in the low-
to-mid-teens as the portfolio of reserves
and mineral interests grows and diversifies.
Mitigation Resources continues to
expand its business, which creates and
sells stream and wetland mitigation credits
and provides services to those engaged in
permittee-responsible mitigation. During
2021, the Mitigation Resources team made
substantial progress on the development
of several projects in Alabama, Mississippi,
Texas and Tennessee. In early 2022,
Mitigation Resources finalized a project to
provide mitigation services for the Lake
Ralph Hall project in Northern Texas, and
it has established a joint venture with
Ecosystems Investment Partners (“EIP”)
related to this project. We are excited to
partner with EIP as they are experts in
restoration and mitigation solutions. All
of these projects align with our long-term
focus and are expected to be accretive to
earnings over the next several years.
We believe Mitigation Resources offers
an opportunity for growth and diversi-
fication in an industry where we have
substantial knowledge and expertise, and
a strong reputation. Our goal is to grow
We remain focused
on creating long-term
shareholder value
this business into one of the ten largest
U.S. providers of mitigation solutions, with
an initial focus on stream and wetland
restoration in the southeast United States.
While this business is in the early stages
of development, we believe Mitigation
Resources can provide solid rates of return
as the business matures.
Overall, our businesses delivered very
strong financial results in 2021, with
reported net income of $48.1 million
compared with $14.8 million in 2020.
NACCO also generated $30.7 million
of cash flow before financing activities
in 2021 and ended the year with $86.0
million of cash and $20.7 million of debt.
We continue to prioritize the protection
of our strong balance sheet and liquidity
position, and we were very pleased to
complete a refinancing of our revolving
credit facility during 2021. We believe
that a strong balance sheet, a solid cash
position and low levels of debt will allow
us to continue to advance our strategic
objectives and generate long-term value.
We are committed to maintaining a
conservative capital structure and avoiding
unnecessary risk. While we are proud of the
hard work that resulted in the significant
improvement in 2021 results, we know we
need to remain focused on our strategies
8
NACCO Industries®
COVID-19 Throughout the
COVID-19 pandemic, the health and
safety of our employees has remained a
top priority. While the pandemic created
challenges for our operations, we addressed
those challenges by establishing and
maintaining enhanced safety measures.
We developed an employee-led cross-
functional team to regularly evaluate COVID
developments and guidance, share best
practices across the Company, and provide
communications to all employees. Each
company operation developed protocols for
executing the enhanced safety measures,
including increased sanitation procedures,
social distancing and masking, responding
quickly to changes in community cases. We
implemented work-from-home plans for
those employees who could effectively work
remotely. Our continued focus has enabled
us to preserve our commitment to keeping
our employees, customers and communities
safe during the pandemic.
Corporate
RESPONSIBILITY
At NACCO, we pride ourselves on a long history of
corporate responsibility, which includes responsible
environmental stewardship, safe operations, community
support and engagement, and a focus on our employees’
wellbeing. As we focus on our two key strategies – Protect
the Core and Grow and Diversify – our commitment to these
principles will guide our efforts.
We maintain sound environmental, social and governance
(“ESG”) practices while our disclosures related to ESG continue
to evolve. We prioritize transparent communication with all
of our key stakeholders – employees, customers, vendors,
suppliers, communities and investors. Our employee-led ESG
Advisory Group helps shape our corporate responsibility and
environmental, health and safety initiatives. We’ve established
four ESG pillars: people, environmental stewardship, safety
and community.
People
We believe our employees fuel our success. The Company provides employee
wages that are competitive and consistent with employee positions, skill levels,
experience, knowledge and geographic location. We are committed to providing a
fair and living wage to all employees. We continue to evolve our programs to meet
employees’ physical and mental health and financial and wellness needs.
We believe training is a critical component for employee well-being. Training
ranges from equipment-specific task training and enhanced safety procedures
to leadership and management training, ethics training and personal
financial wellness, to name a few. Employees are encouraged to pursue
continued professional development, skills training and other educational
opportunities. We offer company-wide training programs across all
levels of management including an educational initiative under
which identified employees participate in a program focused on
management and leadership development, preparing our future
leaders for the next steps in their careers. In addition, qualified
employees are eligible to participate in a tuition reimbursement
program to advance their formal education.
We enjoy high retention among our employees, with our
most tenured employee celebrating 45 years with the
Company in 2021. We have 220 employees, or 14 percent,
who have at least 20 years of service, and our average
tenure is 11 years of service. Our newer employees
benefit from experienced employee mentors and
training programs designed to equip them with
long-lasting skills.
NACCO Industries®
Environmental
STEWARDSHIP
We are committed to being good stewards of the environment. All aspects of our
work must be accomplished in an environmentally responsible manner. Our ESG
Advisory Group and our many environmental professionals monitor environmental
trends to address stakeholder priorities and identify best practices. Our Environmental
Policy, which can be found on our website, emphasizes our strong legacy of environ-
mental stewardship and our commitment to being a good corporate citizen.
Complying with environmental regulations is our minimum standard, and we main-
tain a commitment to meet or exceed all applicable environmental laws and regulations.
Going beyond the minimum is embedded in our culture and allows us to build trust
with our stakeholders. As a result of our commitment, we have received more than 95
awards for successful and innovative reclamation projects over the last 30 years.
We know water is integral to our operations, and we recognize our responsibility to
effectively manage our water resources through conservation, reuse and recycling. We
do not engage in coal washing activities. Rather, we extract lignite from the ground and
deliver it directly to our customers, which minimizes the impact on water resources. We
are also focused on minimizing the consumption of fresh water. The water that we use
comes from a variety of sources, including recycled water from adjacent power plants,
stormwater, and groundwater for dust suppression and vehicle maintenance. Some
of our operations rely on potable water purchased from public water systems. When
stormwater cannot be reused, we collect and treat it to meet applicable standards
before it is released. Water use varies by location; therefore, each mine aligns its water
management strategy with the specific challenges found at its location. As of December
31, 2021, we have no operations that are within regions with “high or extremely high
baseline water stress.”
We are committed to being good
stewards of the environment
We do not maintain any coal waste impoundments. Our operations employ waste
management practices that minimize overall waste products and maximize recycling
and reuse opportunities before proper disposal. We monitor materials, packaging
and waste to identify hazardous materials and conduct periodic audits of the vendors
involved in removing waste from our mine sites. Each of our mining operations is
classified as a very small quantity generator of hazardous waste.
Regulators perform monthly environmental inspections at our coal mining oper-
ations. During 2021, five of our operations celebrated over five years with no mining
permit violations, and three of those have not had a violation in more than ten years.
10
We strive to minimize surface distur-
bance, and we practice contemporaneous
reclamation at our coal mining operations.
We develop effective reclamation plans
that achieve the designated post-mining
use of the land. In addition, our overall
approach to environmental stewardship
seeks to minimize and mitigate impacts
to biodiversity. Prior to initiating mining
activities, we conduct exhaustive bio-
logical surveys to determine if protected
species and/or sensitive habitats are pres-
ent and to understand potential impacts
to local ecosystems. Where impacts are
unavoidable, we develop enhanced
mitigation and/or reclamation strategies
that meet regulatory agency approval.
Our native grass programs at our North
Dakota, Texas, and Mississippi operations
exemplify our commitment to going
above and beyond. At each location,
hundreds of acres of native grasses have
been successfully planted, resulting in
healthy native bird populations in the
reclaimed areas. In North Dakota, a sharp-
tailed grouse habitat has been successfully
established, while in Texas and Mississippi,
bobwhite quail are frequently observed
Safety
We operate in a culture committed to
safety excellence. We expect employees
to work safely and look out for each other.
As described in our Health and Safety
Principles, which can be found on our
website, we commit to every employee
that we will provide a safe working
environment, and in return we ask every
employee to commit to working in a safe
manner so that all of our employees go
home safely at the end of each day. We
actively engage with all employees in
pursuing the objective of zero incidents
and injuries. Our operations have on-site
safety personnel that are responsible for
training employees in safe work practices,
reviewing safety-related incidents and
recommending improvements when
appropriate. We continue to prioritize
investigations of near-miss events
to identify opportunities to improve
employee awareness and incorporate
policy or procedural changes or training,
as appropriate.
Based on Mine Safety and Health
Administration (“MSHA”) data, the
National Mining Association ranks us as
an industry leader in safety, and our
MSHA lost-time incident rate is consis-
tently below the national average for
comparable mines. Our safety perfor-
mance reflects our belief that workplace
incidents and injuries can be prevented
through a focus on continuous improve-
ment and personal responsibility.
We improve our skills as safe miners
through training, which includes practice
drills. Certain operations maintain rescue
teams that may be called upon if an
emergency happens. These teams practice
2021 Annual Report
their skills regularly and participate in
events that assess the ability of teams to
work together in high-pressure scenarios.
During 2021, rescue teams from Coteau
and Falkirk participated in the Rocky
Mountain Mining Institute mine rescue
team evaluation.
We have established a Safe Work Area
Task Force (“SWAT”) Team. The SWAT
team is comprised of safety employees
from across the Company who travel to
different locations to provide a “fresh
eye” regarding safety practices. The
SWAT group works to share findings and
solutions and provides an opportunity
to exchange best practices and ideas
across the Company.
More than 100 safety
awards have been
earned at the state and
national levels
We are proud that we have earned
more than 100 safety awards at the state
and national levels. During 2021, the
Coyote Creek Mine received a special
recognition award from the Lignite Energy
Council for achieving the lowest overall
accident incident rate in the North Dakota
lignite industry in 2020. Additionally, the
Coteau and Falkirk mines were recognized
with Distinguished Safety Awards from
the Lignite Energy Council for having
an accident incident rate lower than the
national average.
11
in mine reclamation areas. A variety
of species voluntarily return to the
reclaimed environment, including bald
eagles, deer, turkeys and moose.
During 2021, Mississippi Lignite Mining
Company received bond release for
1,355 acres of reclaimed land. This land
will be used for recreational, industrial,
aquatic and forestry endeavors, including
a trophy fishery. This beautiful area
includes the natural stream that flows
through the heart of the property, which
won a Reclamation of Excellence award
in 2014 from the Office of Surface Mining
Reclamation and Enforcement. The Arbor
Day Grove that sits on reclaimed land
hosts a variety of trees planted by local
elementary students as part of Arbor Day
celebrations over the past ten years.
Our commitment to the environment
extends beyond compliance, and led
us to create our Mitigation Resources
of North America business, which is
dedicated to developing and protecting
streams and wetlands. This business
builds on our skills, the experience
of our people and our reputation as
thoughtful stewards for the environment,
while allowing us to deliver tangible
environmental benefits for others. To
date, Mitigation Resources has restored
and/or enhanced over 131 acres of
wetlands and over six miles of streams.
Permanent deed restrictions are placed
on these improved streams and wetlands
by Mitigation Resources to prevent other
disturbances or development on these
protected areas.
NACCO Industries®
Community
We believe in making long-term investments in the areas where we operate. We
support numerous charitable efforts in communities where our employees live and
work, including literacy programs as well as local educational and arts organizations.
We believe contributing both time and resources strengthens our community bond.
We contributed over $425,000 during 2021 to organizations that serve the commu-
nities where we operate. One such organization is the Dolly Parton Imagination Library,
which promotes literacy by providing free, age-appropriate books to children from birth
to age 5. We understand the value of education, and we are proud to contribute funding
and time in support of this very worthwhile program. We also support employee cash
donations to qualified organizations through our matching gift program whereby
NACCO will match eligible employee donations up to $5,000 per year, per employee.
In 2021, the Office of Surface Mining Reclamation and Enforcement awarded
Mississippi Lignite Mining Company (“MLMC”) the Excellence in Surface Coal Mining
Reclamation Good Neighbor Award. This national award recognizes successful relation-
ships between mine operators and surrounding landowners and communities. The 2021
award recognized MLMC for its Arbor Day program for local fourth grade students that
it hosts in partnership with the Natural Resources Conservation Service. Students visit
the mine and plant trees to celebrate the importance of forestry and receive a hard-
wood tree sapling to plant in their community. The students also participate in contests
encouraging them to learn about environmental topics such as watersheds, soils, trees,
and pollinators. Also, MLMC often donates bales of Bermuda grass hay produced on
reclaimed prime farmland soils to local charitable organizations such as the Palmer
Home for Children and the Mississippi State University Therapeutic Riding Program.
We regularly host students, teachers and community groups on mine tours and
other educational programs. As an example, the Sabine Mine partnered with the Texas
Corporate Governance
NACCO Industries is governed at the
highest level by a 12-member Board of
Directors, which has long maintained
strong governance practices designed
to ensure accountability, fiscal respon-
sibility and the highest levels of ethical
conduct. Each independent board
member serves on one or more of three
standing committees: Audit Review;
Compensation and Human Capital; and
Nominating and Corporate Governance.
Each committee has a formal charter
that describes its purpose, composition,
duties and responsibilities, including its
role in the Company’s ESG strategy.
Independence is an important compo-
nent of our Board’s oversight, and each
of the chairs of the standing committees
is independent. The board conducts
annual self-evaluations to determine
whether it and its committees are func-
tioning effectively. We believe that good
corporate governance and long-term
success are inextricably linked.
Our Code of Conduct, Corporate
Governance Guidelines, Insider
Trading Policy and Anti-Corruption
Policy require employees to comply
with applicable laws and regulations,
maintain high ethical standards and
report situations of actual or potential
noncompliance. Ethics are deeply
embedded in our values and business
processes. We also maintain an ethics-
related hotline, managed by a third
party, through which individuals can
anonymously raise concerns or ask
questions about business behavior.
Contributing both time
and resources
strengthens our
community bond
Mining and Reclamation Association
to offer a free five-day summer
workshop to educators. The workshop
provided science-based information
to help educate participants about the
availability, importance, development
and use of our natural resources while
protecting our environment. Attendees
toured the mine, visited reclamation
areas, heard from industry experts
and participated in hands-on labs. The
workshop demonstrated a variety of
interactive exercises that teachers can
take back to their classrooms, such as
assessing the physical properties of soil
and rock, how to ensure water quality
meets regulatory standards and how
lignite is used to make electricity.
In recent years, data privacy and
cybersecurity have become key
governance priorities for companies.
We continue to strengthen our
capabilities in this area through several
measures including the establishment
of an internal cybersecurity task force,
ongoing investment in software and
other security tools, and the use of
third-party cybersecurity experts
performing a variety of activities
including but not limited to continuous
system monitoring and penetration
testing. We are continually focused on
improving employees’ cybersecurity
awareness through training on topics
such as password best practices and
phishing identification.
LOOKING AHEAD, we expect to build on our commitments to environmental stewardship, to the safety and well-being of our
employees, and to the improvement of the communities where they live and work. Our key strategies – Protect the Core and
Grow and Diversify – guide us as we invest in our businesses and deliver value for shareholders.
Our Company was founded in 1913, and descendants of Frank Taplin, our founder, continue to own a substantial portion of
our stock today. Five generations of stock ownership provide a long-term perspective that few companies enjoy. A clear, well-
thought-out approach to corporate governance allows our management team to focus on running the Company and doing what
is right, with a long-term perspective. We believe that short-term perspectives fall short when thinking about transformational
business strategies that can take years to develop and implement. Our Board of Directors, management team and employees
are aligned in expectations that everyone has responsibility for operating ethically, responsibly and safely at every level of our
business. It is always the right thing to do.
12
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, DC 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
or
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
Commission File No. 1-9172
NACCO INDUSTRIES, INC.
(Exact name of registrant as specified in its charter)
Delaware
(State or other jurisdiction of incorporation or organization)
34-1505819
(I.R.S. Employer Identification No.)
5875 Landerbrook Drive, Suite 220
Cleveland, Ohio
(Address of principal executive offices)
44124-4069
(Zip Code)
Securities registered pursuant to Section 12(b) of the Act
Registrant's telephone number, including area code: (440) 229-5151
Title of each class
Trading Symbol
Name of each exchange on which registered
Class A Common Stock, $1 par value per share
NC
New York Stock Exchange
Class B Common Stock is not publicly listed for trade on any exchange or market system; however, Class B Common Stock is convertible into Class A
Common Stock on a share-for-share basis.
Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.
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 þ
Yes ¨ No þ
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 þ 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 þ 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 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 ☐
Accelerated filer
☑ Non-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. o
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. ☑
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act)
Yes ☐ No ☑
Aggregate market value of Class A Common Stock and Class B Common Stock held by non-affiliates as of June 30, 2021 (the last business day of the
registrant's most recently completed second fiscal quarter): $109,032,630
Number of shares of Class A Common Stock outstanding at February 18, 2022: 5,616,768
Number of shares of Class B Common Stock outstanding at February 18, 2022: 1,566,413
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the Company's Proxy Statement for its 2022 annual meeting of stockholders are incorporated herein by reference in Part III of this Form 10-K.
NACCO INDUSTRIES, INC.
TABLE OF CONTENTS
PART I.
PART II.
Item 1.
BUSINESS
Item 1A. RISK FACTORS
Item 1B. UNRESOLVED STAFF COMMENTS
Item 2.
PROPERTIES
Item 3.
LEGAL PROCEEDINGS
Item 4. MINE SAFETY DISCLOSURES
PAGE
1
20
31
31
43
43
Item 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER
44
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
Item 9C. DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS
Item 10. DIRECTORS, EXECUTIVE OFFICERS 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 ACCOUNTANT FEES AND SERVICES
PART III.
PART IV.
Item 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
SIGNATURES
FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
44
45
60
60
60
60
60
60
61
61
61
61
61
62
69
F-1
Item 1. BUSINESS
PART I
General
NACCO Industries, Inc.® (“NACCO” or the “Company”) brings natural resources to life by delivering aggregates, minerals,
reliable fuels and environmental solutions through its robust portfolio of NACCO Natural Resources businesses. The Company
operates under three business segments: Coal Mining, North American Mining ("NAMining") and Minerals Management. The
Coal Mining segment operates surface coal mines for power generation companies and an activated carbon producer. The
NAMining segment is a trusted mining partner for producers of aggregates, lithium and other minerals. The Minerals
Management segment, which includes the Catapult Mineral Partners (“Catapult”) business, acquires and promotes the
development of mineral interests. In addition, Mitigation Resources of North America® (“Mitigation Resources”) provides
stream and wetland mitigation solutions.
The Company has items not directly attributable to a reportable segment that are not included as part of the measurement of
segment operating profit, which primarily includes administrative costs related to public company reporting requirements at the
parent company and the financial results of Mitigation Resources and Bellaire Corporation ("Bellaire"). Bellaire manages the
Company’s long-term liabilities related to former Eastern U.S. underground mining activities.
NACCO was incorporated as a Delaware corporation in 1986 in connection with the formation of a holding company structure
for a predecessor corporation organized in 1913.
Business Strategy
During 2021, the Company launched a new branding campaign. The new branding creates a unified identity and underscores
NACCO’s commitment to all of its businesses, while focusing on the execution of its two key strategies – Protect the Core and
Grow and Diversify. NACCO’s portfolio of businesses now operates under the umbrella of NACCO Natural Resources. The
new branding provides each business with its own unique identity that can easily be linked back to the NACCO legacy brand
and includes new websites for each business, including NACCO Natural Resources, new business-specific logos and a new
tagline “Bringing Natural Resources to Life”.
The Company is pursuing growth and diversification by strategically leveraging its core mining and natural resources
management skills to build a strong portfolio of affiliated businesses. Management continues to be optimistic about the long-
term outlook for growth in the NAMining and Minerals Management segments and in the Company's Mitigation Resources
business. Each of these businesses continues to expand its pipeline of potential new projects with opportunities for growth and
diversification.
NAMining is pursuing growth and diversification by expanding the scope of its business development activities to include
potential customers who require a broad range of minerals and materials and by leveraging the Company’s core mining skills to
expand the range of contract mining services it provides. The goal is to build NAMining into a leading provider of contract
mining services for customers who produce a wide variety of minerals and materials. The Company believes NAMining can
grow to be a substantial contributor to operating profit, delivering unlevered after-tax returns on invested capital in the mid-
teens as this business model matures and achieves significant scale, but the pace of achieving these objectives will be dependent
on the mix and scale of new projects.
The Minerals Management segment continues to grow and diversify by selectively acquiring mineral and royalty interests in the
United States, in a market and price environment that the Company believes remains well-aligned with its strategy and
objectives. The Minerals Management segment will benefit from the continued development of its mineral properties without
additional capital investment, as all further development costs are borne entirely by third-party producers who lease the
minerals. The Company believes this business model can deliver substantial operating margins over the life of a reserve without
the costs and risk that traditional oil and gas companies bear for the cost of exploration, production and/or development.
Catapult, the Company’s business unit focused on managing and expanding the Company’s portfolio of oil and gas mineral and
royalty interests, has developed a strong network to source and secure new acquisitions, and has several potential acquisitions
under review. The goal is to construct a diversified portfolio of high-quality oil and gas mineral and royalty interests in the
United States that deliver near-term cash flow yields and long-term projected growth. The Company believes this business will
provide unlevered after-tax returns on invested capital in the low-to-mid-teens as the portfolio of reserves and mineral interests
grows and this business model matures.
Mitigation Resources continues to expand its business, which creates and sells stream and wetland mitigation credits and
provides services to those engaged in permittee-responsible mitigation. This business offers an opportunity for growth and
diversification in an industry where the Company has substantial knowledge and expertise and a strong reputation. The
Mitigation Resources business has achieved several early successes and is positioned for additional growth. The Company's
1
goal is to grow Mitigation Resources into one of the ten largest U.S. providers of mitigation solutions, largely focused on
streams and wetlands, initially in the southeast United States. While this business is in the early stages of development, the
Company believes that Mitigation Resources can provide solid rates of return as this business matures.
The Company also continues to pursue activities which can strengthen the resiliency of its existing coal mining operations. The
Company remains focused on managing coal production costs and maximizing efficiencies and operating capacity at mine
locations to help customers with management fee contracts be more competitive. These activities benefit both customers and
the Company's Coal Mining segment, as fuel cost is a significant driver for power plant dispatch. Increased power plant
dispatch results in increased demand for coal by the Coal Mining segment's customers. Fluctuating natural gas prices and
availability of renewable energy sources, such as wind and solar, affect the amount of electricity dispatched from coal-fired
power plants. Coal and natural gas traditionally have been the two largest sources of electricity generation in the United States.
In many areas of the country, these two fuels compete to supply electricity based on their relative costs. U.S. natural gas prices
have been more volatile than coal prices, so the cost of natural gas often determines the relative share of generation provided by
natural gas and coal. Between 2015 and 2020, the cost of natural gas delivered to electric generators remained relatively low
and stable. During 2021, however, natural gas prices were much higher than in recent years, generally resulting in increased
dispatch of coal-fired power plants.
The Company continues to look for opportunities to expand its coal mining business where it can apply its management fee
business model to assume operation of existing surface coal mining operations in the United States. However, opportunities are
very limited in the current environment. In addition, the political and regulatory environment is not receptive to development of
new coal-fired power generation projects which would create opportunities to build and operate new coal mines.
The Company is committed to maintaining a conservative capital structure as it continues to grow and diversify, while avoiding
unnecessary risk. Strategic diversification will generate cash that can be re-invested to strengthen and expand the businesses. In
all of its business endeavors, the Company continues to maintain the highest levels of customer service and operational
excellence, with an unwavering focus on safety, environmental stewardship and people. The Company is passionately
committed to working hard, doing what’s right, and bringing America's natural resources to life.
Business Developments
Coal Mining Segment
Effective September 30, 2021, the contract mining agreement between Bisti Fuels Company, LLC (“Bisti”) and its customer,
Navajo Transitional Energy Company ("NTEC") was terminated. As required under the agreement, NTEC paid the Company a
termination fee of $10.3 million. As of October 1, 2021, NTEC assumed control and responsibility for operation and all
reclamation of the Navajo Mine.
The Coteau Properties Company (“Coteau”) operates the Freedom Mine in North Dakota. All coal production from the
Freedom Mine is delivered to Basin Electric Power Cooperative (“Basin Electric”). Basin Electric utilizes the coal at the Great
Plains Synfuels Plant (the “Synfuels Plant”), Antelope Valley Station and Leland Olds Station. The Synfuels Plant is a coal
gasification plant, owned by Dakota Gasification Company (“Dakota Gas’), a subsidiary of Basin Electric, that manufactures
synthetic natural gas and produces fertilizers, solvents, phenol, carbon dioxide, and other chemical products for sale. During
2020, Basin Electric informed Coteau that it is considering changes that may result in modifications to its Synfuels Plant that
could potentially reduce or eliminate coal requirements at the Synfuels Plant. During August 2021, Bakken Energy (“Bakken”)
and Basin Electric signed a non-binding term sheet to transfer ownership of the assets of Dakota Gas to Bakken. Bakken stated
the closing date is expected to be April 1, 2023. As part of the term sheet between Basin Electric and Bakken, Basin Electric
indicated that the Synfuels Plant will continue existing operations through 2025. The closing is subject to the satisfaction of
specified conditions. Basin Electric is also considering other options for the Synfuels Plant if the transaction with Bakken does
not close. Basin Electric indicated that if it decides to proceed with any changes that could reduce or eliminate the use of coal,
the feedstock change is not expected to occur before 2026.
The Falkirk Mining Company ("Falkirk") operates the Falkirk Mine in North Dakota. Falkirk is the sole supplier of lignite coal
to the Coal Creek Station power plant pursuant to a contract under which Falkirk also supplies approximately 0.3 million tons
of lignite coal per year to Spiritwood Station power plant. Coal Creek Station and Spiritwood Station are owned by Great River
Energy (“GRE”). In May 2020, GRE announced its intent to sell or retire Coal Creek Station and modify Spiritwood Station to
be fueled by natural gas.
During June 2021, GRE entered into an agreement to sell Coal Creek Station and the adjacent high-voltage direct current
transmission line to Bismarck, North Dakota-based Rainbow Energy Center, LLC (“Rainbow Energy”) and its affiliates. The
2
closing of this sale is subject to the satisfaction of certain conditions and presently, the transaction is expected to close in the
second quarter of 2022.
Upon completion of the sale of Coal Creek Station, the existing Coal Sales Agreement, the existing Mortgage and Security
Agreement and the existing Option Agreement between GRE and Falkirk will terminate. Falkirk and GRE have entered into a
termination and release of claims agreement. Upon completion of the sale of Coal Creek Station, GRE will pay Falkirk
$14.0 million in cash, as well as transfer ownership of an office building located in Bismarck, North Dakota, and convey
membership units in Midwest AgEnergy to The North American Coal Corporation® (“NACoal”), a wholly-owned subsidiary
of NACCO. NACCO currently holds a $5.0 million investment in Midwest AgEnergy, which operates two ethanol facilities in
North Dakota.
If GRE's efforts to sell the power plant are successful, a new Coal Sales Agreement (“CSA”) between Falkirk and Rainbow
Energy will become effective and Falkirk will supply all coal requirements of Coal Creek Station concurrent with Rainbow
Energy’s acquisition of the power plant. Falkirk will no longer make any coal deliveries to GRE’s Spiritwood Station. Falkirk
will be paid a management fee and Rainbow Energy will be responsible for funding all mine operating costs and directly or
indirectly providing all of the capital required to operate the mine. The CSA specifies that Falkirk will perform final mine
reclamation, which will be funded in its entirety by Rainbow Energy. The initial production period is expected to run ten years
from the effective date of the CSA, but the CSA may be extended or terminated early under certain circumstances. If Rainbow
Energy terminates the CSA and closes Coal Creek Station before 2027, Falkirk will be entitled to an additional payment from
GRE under the terms of the termination and release of claims agreement. The additional payment amount ranges from
$8 million if the closure occurs before 2024 to $2 million if the closure occurs in 2026. To support the transfer to new
ownership, Falkirk has agreed to a reduction in the current per ton management fee from the effective date of the new CSA
through May 31, 2024. After May 31, 2024, the per ton management fee increases to a higher base in line with current fee
levels, and thereafter adjusts annually according to an index which tracks broad measures of U.S. inflation.
If GRE’s efforts to sell the power plant are not successful and GRE elects to prematurely close Coal Creek Station, the early
termination of the CSA would have a material adverse effect on the Company's business, financial condition and results of
operations.
The Sabine Mining Company (“Sabine”) operates the Sabine Mine in Texas. All production from Sabine is delivered to
Southwestern Electric Power Company's (“SWEPCO”) Henry W. Pirkey Plant (the “Pirkey Plant”). SWEPCO is an American
Electric Power (“AEP”) company. During 2020, AEP announced its intent to retire the Pirkey Plant in 2023. SWEPCO expects
deliveries from Sabine to continue until the first quarter of 2023 at which time Sabine expects to begin final reclamation.
Funding for mine reclamation is the responsibility of SWEPCO.
During 2020, Caddo Creek Resources Company, LLC (“Caddo Creek”) ceased all mining and delivery of lignite and
commenced mine reclamation. Funding for mine reclamation is the responsibility of a subsidiary of Advanced Emissions
Solutions (“AES”). Caddo Creek entered into a contract with a subsidiary of AES to perform the required mine reclamation.
The reclamation at Caddo Creek is expected to be substantially complete during the first half of 2022.
During 2020, the contract mining agreement between Camino Real Fuels, LLC (“Camino Real”) and its customer, Dos
Republicas Coal Partnership (“DRCP”), terminated and resulted in mine closure. Funding for mine reclamation is the
responsibility of DRCP.
NAMining Segment
In the third quarter of 2021, NAMining entered into contracts with a new customer to perform all mining operations at two sand
and gravel quarries located in Texas and Arkansas. The initial term of each contract is two years, and one of the contracts
automatically extends an additional two years provided NAMining is not in default under that contract. In the second quarter of
2021, NAMining entered into a one-year mining services contract with an existing customer for a sand and gravel quarry in
Indiana. In the first quarter of 2021, NAMining entered into a 15-year mining services contract with a new customer at a
limestone quarry in Central Florida. NAMining will operate two smaller draglines at this quarry while it relocates and
commissions a larger dragline that will increase production capacity. The relocated dragline is anticipated to be commissioned
in the second half of 2022. During 2021, NAMining also amended a contract with a current customer to provide additional
services at a limestone quarry in Florida.
In addition, NAMining will serve as exclusive contract miner for the Thacker Pass lithium project in northern Nevada.
Thacker Pass is owned by Lithium Nevada Corp., a subsidiary of Lithium Americas Corp. (TSX: LAC) (NYSE: LAC). Lithium
Americas Corp. owns the lithium reserves at Thacker Pass and will be responsible for the processing and sale of the lithium
3
produced. At maturity, the Thacker Pass management fee contract is expected to deliver fee income similar to a mid-sized
management fee coal mine.
Minerals Management Segment
During 2021 and 2020, the Minerals Management segment acquired additional mineral interests, primarily in the Eagle Ford
and Permian Basins in Texas. During the second quarter of 2021, the Minerals Management segment, through its Catapult
business, acquired a combination of mineral and overriding royalty interests in the Eagle Ford Basin, which includes
approximately 14.1 thousand gross acres and 1.7 thousand net royalty acres, for an initial payment of $4.7 million. Under the
terms of the transaction, Catapult could make additional payments for each additional well developed on the acquired assets
during 2022 of up to a maximum of $0.6 million. Catapult also completed a small acquisition of royalty interests in the
Delaware Basin during 2021 for a purchase price of $0.3 million. Minerals Management intends to continue to make future
acquisitions of mineral and royalty interests that meet the Company’s acquisition criteria as part of its growth strategy.
Operations
Coal Mining Segment
The Coal Mining segment, NACoal, operates surface coal mines under long-term contracts with power generation companies
and an activated carbon producer pursuant to a service-based business model. Coal is surface mined in North Dakota, Texas,
Mississippi and Louisiana. Through September 30, 2021, the Company provided contract mining services on the Navajo Nation
in New Mexico. Each mine is fully integrated with its customer's operations.
During 2021, the Company's operating coal mines were: Bisti, Coteau, Coyote Creek Mining Company, LLC (“Coyote
Creek”), Demery Resources Company, LLC (“Demery”), Falkirk, Mississippi Lignite Mining Company (“MLMC”) and
Sabine.
Coteau, Coyote, Falkirk, MLMC and Sabine supply lignite coal for power generation. Demery supplies lignite coal for the
production of activated carbon products. Each mine is the exclusive supplier of coal to its customers' facilities. Each of these
mines delivers its coal production to adjacent or nearby power plants, synfuels plants or an activated carbon processing facility
under long-term supply contracts. MLMC’s lignite sales agreement contains a minimum annual take provision; all other coal
supply contracts are requirements contracts under which earnings can fluctuate based on customer requirements. Certain coal
supply contracts can be terminated early, which would result in a reduction to future earnings.
At all operating coal mines other than MLMC, the Company is paid a management fee per ton of coal or heating unit (MMBtu)
delivered. Each contract specifies the indices and mechanics by which fees change over time, generally in line with broad
measures of U.S. inflation. The customers are responsible for funding all mine operating costs, including final mine
reclamation, and directly or indirectly provide all of the capital required to build and operate the mine. This contract structure
eliminates the Company's exposure to spot coal market price fluctuations while providing income and cash flow with minimal
capital investment. Other than at Coyote Creek, debt financing provided by or supported by the customers is without recourse to
NACCO and NACoal. See Note 17 to the Consolidated Financial Statements in this Form 10-K for further discussion of Coyote
Creek's guarantees.
All operating coal mines other than MLMC meet the definition of a variable interest entity (“VIE”). In each case, NACCO is
not the primary beneficiary of the VIE as it does not exercise financial control; therefore, NACCO does not consolidate the
results of these operations within its financial statements. Instead, these contracts are accounted for as equity method
investments. The income before income taxes associated with these VIEs is reported as Earnings of unconsolidated operations
on the Consolidated Statements of Operations, and the Company’s investment is reported on the line Investments in
unconsolidated subsidiaries in the Consolidated Balance Sheets. The mines that meet the definition of a VIE are referred to
collectively as the “Unconsolidated Subsidiaries.” For tax purposes, the Unconsolidated Subsidiaries are included within the
NACCO consolidated U.S. tax return; therefore, the income tax expense line on the Consolidated Statements of Operations
includes income taxes related to these entities. See Note 17 to the Consolidated Financial Statements in this Form 10-K for
further information on the Unconsolidated Subsidiaries.
The Company performs contemporaneous reclamation activities at each mine in the normal course of operations. Under all of
the Unconsolidated Subsidiaries’ contracts, the customer has the obligation to fund final mine reclamation activities. Under
certain contracts, the Unconsolidated Subsidiary holds the mine permit and is therefore responsible for final mine reclamation
activities. To the extent the Unconsolidated Subsidiary performs such final reclamation, it is compensated for providing those
services in addition to receiving reimbursement from customers for costs incurred.
4
Caddo Creek met the definition of a VIE prior to the cessation of mining on September 30, 2020. The terms of the contract to
perform mine reclamation contain a fixed-price component and therefore, Caddo Creek has been consolidated within the
Company's financial statements since October 1, 2020.
The MLMC contract is the only operating coal contract in which the Company is responsible for all operating costs, capital
requirements and final mine reclamation; therefore, MLMC is consolidated within NACCO’s financial statements. MLMC sells
coal to its customer at a contractually agreed-upon price which adjusts monthly, primarily based on changes in the level of
established indices which reflect general U.S. inflation rates. Profitability at MLMC is affected by customer demand for coal
and changes in the indices that determine sales price and actual costs incurred. As diesel fuel is heavily weighted among the
indices used to determine the coal sales price, fluctuations in diesel fuel prices can result in significant fluctuations in earnings
at MLMC.
MLMC delivers coal to the Red Hills Power Plant in Ackerman, Mississippi. The Red Hills Power Plant supplies electricity to
the Tennessee Valley Authority ("TVA") under a long-term Power Purchase Agreement ("PPA"). MLMC’s contract with its
customer runs through 2032. TVA’s power portfolio includes coal, nuclear, hydroelectric, natural gas and renewables. The
decision of which power plants to dispatch is determined by TVA. Reduction in dispatch of the Red Hills Power Plant will
result in reduced coal deliveries and earnings at MLMC.
See “Item 2. Properties" on page 31 in this Form 10-K for discussion of the Company's mineral resources and mineral reserves.
NAMining Segment
The NAMining segment provides value-added contract mining and other services for producers of aggregates, lithium and other
minerals. The segment is a primary platform for the Company’s growth and diversification of mining activities outside of the
coal industry. NAMining provides contract mining services for independently owned mines and quarries, creating value for its
customers by performing the mining aspects of its customers’ operations. This allows customers to focus on their areas of
expertise: materials handling and processing, product sales and distribution. NAMining historically operated primarily at
limestone quarries in Florida, but is focused on expanding outside of Florida, mining materials other than limestone and
expanding the scope of mining operations provided to its customers. As of December 31, 2021, NAMining operates mines in
Florida, Texas, Arkansas and Indiana and will serve as exclusive contract miner for the Thacker Pass lithium project in northern
Nevada.
NAMining utilizes both fixed price and management fee contract structures. Certain of the entities within the NAMining
segment are VIEs and are accounted for under the equity method as Unconsolidated Subsidiaries. See Note 17 to the
Consolidated Financial Statements in this Form 10-K for further information on the Unconsolidated Subsidiaries.
Minerals Management Segment
The Minerals Management segment derives income primarily by leasing its royalty and mineral interests to third-party
exploration and production companies, and, to a lesser extent, other mining companies, granting them the rights to explore,
develop, mine, produce, market and sell gas, oil, and coal in exchange for royalty payments based on the lessees' sales of those
minerals.
The acquisition criteria for building a blended portfolio of mineral and royalty interests includes (i) new wells anticipated to
come online within one to two years of investment, (ii) areas with forecasted future development within five years after
acquisition, or (iii) existing producing wells further along the decline curve that will generate stable cash flow. In addition,
acquisitions should extend the geographic footprint to diversify across multiple basins with a preliminary focus on the more oil-
rich Permian basin and a secondary focus on other diversifying basins to increase regional exposure. While the current focus is
on the acquisition of mineral and royalty interests, the Company would also consider investments in overriding royalty
interests, non-participating royalty interests or non-operated working interests under certain circumstances. The current
acquisition strategy does not contemplate any near-term working interest investments in which the Company would act as the
operator.
Total consideration for the 2021 and 2020 acquisitions of mineral and royalty interests was $5.3 million and $14.2 million,
respectively. The 2021 acquisitions include 20.6 thousand gross acres and 1.8 thousand net royalty acres. The 2020 acquisitions
include 65.5 thousand gross acres and 1.2 thousand net royalty acres. Total mineral and royalty interests include approximately
127.8 thousand gross acres and 59.9 thousand net royalty acres at December 31, 2021.
The Company’s legacy royalty and mineral interests are located in Ohio (Utica and Marcellus shale natural gas), Louisiana
(Haynesville shale and Cotton Valley formation natural gas), Texas (Cotton Valley and Austin Chalk formation natural gas),
5
Mississippi (coal), Pennsylvania (coal, coalbed methane and Marcellus shale natural gas), Alabama (coal, coalbed methane and
natural gas) and North Dakota (coal, oil and natural gas). The majority of the Company’s legacy reserves were acquired as part
of its historical coal mining operations.
The Minerals Management segment owns royalty interests, mineral interests, nonparticipating royalty interests, and overriding
royalty interests.
•
Royalty Interest. Royalty interests generally result when the owner of a mineral interest leases the underlying minerals
to an exploration and production company pursuant to an oil and gas lease. Typically, the resulting royalty interest is a
cost-free percentage of production revenues for minerals extracted from the acreage. A holder of royalty interests is
generally not responsible for capital expenditures or lease operating expenses, but may be responsible for certain post-
production expenses, and typically have no environmental liability. Royalty interests expire upon the expiration of the
oil and gas lease.
• Mineral Interest. Mineral interests are perpetual rights of the owner to explore, develop, exploit, mine, and/or produce
any or all of the minerals lying below the surface of the property. The holder of a mineral interest has the right to lease
the minerals to an exploration and production company. Upon the execution of an oil and gas lease, the lessee (the
exploration and production company) becomes the working interest owner and the lessor (the mineral interest owner)
has a royalty interest.
•
•
Non-Participating Royalty Interest (“NPRIs”). NPRI is an interest in oil and gas production which is created from the
mineral estate. The NPRI is expense-free, bearing no operational costs of production. The term “non-participating”
indicates that the interest owner does not share in the bonus, rentals from a lease, nor the right to participate in the
execution of oil and gas leases.
Overriding Royalty Interest (“ORRIs”). ORRIs are created by carving out the right to receive royalties from a working
interest. Like royalty interests, ORRIs do not confer an obligation to make capital expenditures or pay for lease
operating expenses and have limited environmental liability, however ORRIs may be calculated net of post-production
expenses, depending on how the ORRI is structured. ORRIs that are carved out of working interests are linked to the
same underlying oil and gas lease that created the working interest, and therefore, such ORRIs are typically subject to
expiration upon the expiration or termination of the oil and gas lease.
The Company may own more than one type of mineral and royalty interest in the same tract of land. For example, where the
Company owns an ORRI in a lease on the same tract of land in which it owns a mineral interest, the ORRI in that tract will
relate to the same gross acres as the mineral interest in that tract.
The Minerals Management segment will benefit from the continued development of its mineral properties without the need for
investment of additional capital once mineral and royalty interests have been acquired. The Minerals Management segment
does not have any investments under which it would be required to bear the cost of exploration, production or development.
See “Item 2. Properties" on page 31 in this Form 10-K for discussion of the Company's proved reserves.
Customers
The principal customers of the Coal Mining segment are electric utilities, an independent power provider and a producer of
activated carbon.
The principal customers of the NAMining segment are limestone producers and to a lesser extent, sand and gravel producers. In
addition, NAMining will serve as exclusive contract miner for the Thacker Pass lithium project in northern Nevada.
The Minerals Management segment generates income primarily from royalty-based lease payments from oil, gas and to a lesser
extent, coal producers. The pricing of oil, gas and coal sales is primarily determined by supply and demand in the marketplace
and can fluctuate considerably. As a royalty owner and non-operator, the Company has limited access to timely information,
involvement, and operational control over the volumes of oil, gas and coal produced and sold and the terms and conditions on
which such volumes are marketed and sold.
6
In 2021 and 2020, two customers individually accounted for more than 10% of consolidated revenues. The following represents
the revenue attributable to each of these entities as a percentage of consolidated revenues for those years:
Percentage of Consolidated
Revenues
Segment
Coal Mining customer
NAMining customer
2021
2020
43 %
19 %
55 %
19 %
The loss of either of these customers could have a material adverse effect on the results of operations attributable to the
applicable segment and on the Company's consolidated results of operations.
In addition to the customers listed above, the Company has certain subsidiaries that meet the definition of a VIE; therefore,
NACCO does not consolidate the results of these operations within its financial statements. Instead, these contracts are
accounted for as equity method investments. For the year ended December 31, 2021, the Coal Mining segment derived
approximately 68% of the Earnings of Unconsolidated Operations from two customers, Basin Electric and GRE. The loss of
either of these contracts could have a material adverse effect on the Earnings of Unconsolidated Operations of the Coal Mining
segment and a material adverse effect on the Company's Consolidated Statements of Operations.
Competition
The Company's coal mines are directly adjacent to the customer’s property, with economical delivery methods that include
conveyor belt delivery systems linked to the customer’s facilities or short-haul rail systems. All of the mines in the Coal Mining
segment are the most economical suppliers to each of their respective customers as a result of transportation advantages over
competitors. In addition, the customers' facilities were specifically designed to use the coal being mined.
The coal industry competes with other sources of energy, particularly oil, gas, hydro-electric power and nuclear power. In
addition, it competes with subsidized sources of energy, primarily wind and solar. Among the factors that affect competition are
the price and availability of oil and natural gas, environmental and related political considerations, the time and expenditures
required to develop new energy sources, the cost of transportation, the cost of compliance with governmental regulations, the
impact of federal and state energy policies, the impact of subsidies on renewable pricing and the Company's customers' dispatch
decisions, which may also take into account carbon dioxide emissions. The ability of the Coal Mining segment to maintain
comparable levels of coal production at existing facilities and to market and develop its reserves will depend upon the
interaction of these factors.
Electricity generating units are chosen to run primarily based on operating costs, of which fuel costs account for the largest
share. Natural gas-fired power plants have the most potential to continue to displace coal-fired electric baseload power
generation in the near term. There also continues to be an increase in the amount of electricity generated by wind and solar.
Fluctuations in natural gas prices and the availability of renewable generation, particularly wind, can contribute to changes in
power plant dispatch and customer demand for coal. The significant increase in natural gas prices in 2021 compared to natural
gas prices in 2020 contributed to an increase in customer power plant dispatch and coal deliveries in 2021. Sustained higher
natural gas prices could lead to increased demand for coal and positively affect Coal Mining segment results. Over the longer
term, the Company continues to believe that customer demand will remain pressured by continuing increases in subsidized
renewable generation sources, particularly wind. Federal and state mandates for increased use of electricity derived from
renewable energy sources have also negatively affected demand for coal. Such mandates, combined with other incentives to use
renewable energy sources, such as tax credits, make alternative fuel sources competitive with coal. The Taxpayer Certainty and
Disaster Tax Relief Act of 2020 extended the production tax credit (“PTC”) under Section 45 of the Internal Revenue Code and
the investment tax credit (“ITC”) under Section 48 of the Code. The PTC for wind was extended at the current phase-out level
(60% of the otherwise allowable credits) for facilities where construction began in 2021. The ITC for solar was extended at
26% for energy property where construction begins in 2021-2022 and at 22% where construction begins in 2023-2025. Solar
energy property placed in service after December 31, 2025 will receive a 10% ITC. Environmental, social and governance
considerations can also have an impact on power plant dispatch and demand for coal.
Based on industry information, the Company believes it was one of the ten largest coal producers in the U.S. in 2021 based on
total coal tons produced.
NAMining faces competition from producers of aggregates, lithium or other minerals that choose to self-perform mining
operations and from other mining companies.
7
In the Minerals Management segment, the oil and gas industry is intensely competitive; the Company primarily competes with
companies and investors for the acquisition of oil and gas properties, some of which have greater resources and may be able to
pay more for productive oil and natural gas properties or to define, evaluate, bid for and purchase a greater number of properties
than the Company’s financial resources permit. Additionally, many of the Minerals Management segment's competitors are, or
are affiliated with, operators that engage in the exploration and production of their oil and gas properties, which allows them to
acquire larger assets that include operated properties. Larger or more integrated competitors may be able to absorb the burden
of existing, and any changes to, federal, state and local laws and regulations more easily than the Company can, which would
adversely affect its competitive position. The integrated competitors may also have a better understanding of when minerals
they acquire will be developed, as they are often the developer. The Minerals Management segment’s ability to acquire
additional properties in the future will be dependent upon its ability to evaluate and select suitable properties and to
consummate transactions in a highly competitive environment. In addition, because the Company has fewer financial resources
than many companies in the oil and gas industry, the Company may be at a disadvantage in bidding for oil and natural gas
properties.
Seasonality
The Company has experienced limited variability in its results due to the effect of seasonality; however, variations in coal
demand can occur as a result of the timing and duration of planned or unplanned outages at customers' facilities. Variations in
coal demand can also occur as a result of changes in market prices of competing fuels such as natural gas, wind and solar power
and demand for electricity, which can fluctuate based on changes in weather patterns.
The NAMining segment extracts a significant amount of the annual limestone produced in Florida. The Florida construction
industry can be affected by the cyclicality of the economy, seasonal weather conditions and pandemics, all of which can result
in variations in demand for aggregates.
In the Minerals Management segment, oil and natural gas wells have high initial production rates and follow a natural decline
before settling into relatively stable, long-term production. Decline rates can vary due to factors like well depth, well length,
geology, formation pressure, and facility design. In addition to the natural production decline curve, royalty income can
fluctuate favorably or unfavorably in response to a number of factors outside of the Company's control, including the number of
wells being operated by third parties, fluctuations in commodity prices (primarily oil and natural gas), fluctuations in
production rates associated with operator decisions, regulatory risks, the Company's lessees' willingness and ability to incur
well-development and other operating costs, and changes in the availability and continuing development of infrastructure.
Human Capital
As of December 31, 2021, the Company and its subsidiaries had approximately 1,600 employees, including approximately
1,100 employees at the Company’s unconsolidated mining operations, none of which are represented by a collective bargaining
agreement. NACCO believes it has good relations with its employees.
Market-Based Compensation: NACCO believes its employees are critical to its success and invests in its employees by offering
a market-based competitive total rewards package that includes a combination of salaries and wages and a benefits package that
promotes employee well-being across all aspects of their lives. The Company provides employee wages that are competitive
and consistent with employee positions, skill levels, experience, knowledge and geographic location. Benefits offered to
employees include:
• Medical, dental and vision benefits for employee, spouse and dependents;
Flexible spending accounts for both healthcare and dependent care;
•
Health savings accounts and health reimbursement accounts, both of which receive a company contribution;
•
Paid vacation and holidays;
•
Parental leave;
•
•
Short-term and long-term disability benefits;
• Wellness incentives for employees;
Life and AD&D insurance benefits;
•
Charitable donation matches; and
•
Employee assistance program.
•
Employee Development: The Company recognizes that its culture and success is strengthened when employees are respected,
motivated and engaged. The Company works to match employees with assignments that capitalize on the skills, talents and
potential of each employee. The Company believes in hiring, engaging, developing and promoting people who are fully able to
meet the demands of each position, regardless of race, color, religion, gender, sexual orientation, gender identity, national
origin, age, veteran status or disability.
8
Safety: Employee safety in the workplace is one of the Company’s core values. The Company is committed to strict compliance
with applicable laws and regulations regarding workplace safety and provides on-going safety training, education and
communication. Hazards in the workplace are actively identified and management tracks incidents so remedial actions can be
taken to improve workplace safety. The Company believes communication related to “near misses,” safety incidents and
protocols is essential to continuously developing and maintaining best-practices related to safety and enables identification and
correction of operational practices that might impair employee safety or health.
Company Ethics: The Company has processes in place for compliance with its Code of Corporate Conduct, Insider Trading
Policy and Anti-Corruption Policy. All of the Company's Directors and employees annually complete certifications with respect
to compliance with the Company's Code of Corporate Conduct. In addition, all employees of the Company are required to
complete annual Code of Corporate Conduct training. Ethics are deeply embedded in the Company’s values and business
processes. The Company also maintains an ethics related hotline, managed by a third party, through which individuals can
anonymously raise concerns or ask questions about business behavior.
Community Engagement: The Company supports its local communities and is committed to helping them remain safe, healthy
and resilient. The Company's past activities include corporate donations, volunteerism and education. Community engagement
is encouraged and supported through the Company's matching gift program. The Company will match employee contributions
up to $5,000 per employee if program criteria are met.
Available Information
The Company makes its annual reports on Form 10-K, quarterly reports on Form 10-Q, current reports on Form 8-K, and any
amendments to those reports available, free of charge, through its website, www.nacco.com, as soon as reasonably practicable
after such material is electronically filed with, or furnished to, the Securities and Exchange Commission (“SEC”). The content
of the Company's website is not incorporated by reference into this Form 10-K or in any other report or document filed with the
SEC, and any reference to the Company's website is intended to be an inactive textual reference only.
Under Rule 12b-2 of the Exchange Act, the Company qualifies as a “smaller reporting company” because its public float as of
the last business day of the Company’s most recently completed second quarter was less than $250 million. For as long as the
Company remains a “smaller reporting company,” it may take advantage of certain exemptions from the SEC’s reporting
requirements that are otherwise applicable to public companies that are not smaller reporting companies.
Government Regulation
The Company's operations are subject to various federal, state and local laws and regulations on matters such as employee
health and safety, and certain environmental laws and regulations relating to, among other matters, the reclamation and
restoration of coal mining properties, air pollution, water pollution, the disposal of wastes and effects on groundwater. In
addition, the electric power generation industry is subject to extensive regulation regarding the environmental impact of its
power generation activities that could affect demand for coal from the Company's Coal Mining segment. Many aspects of the
production, pricing and marketing of oil and natural gas are regulated by federal and state agencies. Legislation affecting the oil
and natural gas industry is under constant review for amendment or expansion, which frequently increases the regulatory
burden on affected members of the industry and could affect the results of the Company’s Minerals Management segment.
Numerous governmental permits and approvals are required for coal mining operations. The Company's subsidiaries hold or
will hold the necessary permits at all of its coal mining operations except Demery and Caddo Creek, where the customers hold
the respective permits. The Company believes, based upon present information provided to it by these third-party mine permit
holders, that these third parties have all permits necessary for the Company to operate or reclaim Caddo Creek and Demery;
however, the Company cannot be certain that these third parties will be able to maintain all such permits in the future.
At the coal mining operations where the Company's subsidiaries hold the permits, the Company is required to prepare and
present to federal, state or local governmental authorities data pertaining to the effect or impact that any proposed exploration
for or production of coal may have upon the environment and public and employee health and safety.
Some laws, as discussed below, place many requirements on the coal mining operations and the limestone quarries where the
Company provides services. Federal and state regulations require regular monitoring of the Company's operations to ensure
compliance.
9
Mine Health and Safety Laws
The Federal Mine Safety and Health Act of 1977 imposes safety and health standards on all mining operations. Regulations are
comprehensive and affect numerous aspects of mining operations, including training of mine personnel, mining procedures,
blasting, the equipment used in mining operations and other matters. The Federal Mine Safety and Health Administration
enforces compliance with these federal laws and regulations.
Environmental Laws
The Company's coal mining operations are subject to various federal environmental laws, as amended, including:
•
•
•
•
•
•
the Surface Mining Control and Reclamation Act of 1977 (“SMCRA”);
the Clean Air Act, including amendments to that act in 1990 (“CAA”);
the Clean Water Act of 1972 (“CWA”);
the Resource Conservation and Recovery Act ("RCRA");
the National Environmental Policy Act of 1970 (“NEPA”); and
the Comprehensive Environmental Response, Compensation and Liability Act ("CERCLA").
In addition to these federal environmental laws, various states have enacted environmental laws that provide for higher levels of
environmental compliance than similar federal laws. These state environmental laws require reporting, permitting and/or
approval of many aspects of coal mining operations. Both federal and state inspectors regularly visit mines to enforce
compliance. The Company has ongoing training, compliance and permitting programs to ensure compliance with such
environmental laws. Changes in environmental laws and regulations occur frequently, and any changes that result in more
stringent and costly pollution control or waste handling, storage, transport, disposal or cleanup requirements could materially
adversely affect the Coal Mining segment.
Surface Mining Control and Reclamation Act
SMCRA establishes mining, environmental protection and reclamation standards for all aspects of surface coal mining
operations. Where state regulatory agencies have adopted federal mining programs under SMCRA, the state becomes the
primary regulatory authority.
Coal mine operators must obtain SMCRA permits and permit renewals for coal mining operations from the applicable
regulatory agency. These SMCRA permit provisions include requirements for coal prospecting, mine plan development, topsoil
removal, storage and replacement, selective handling of overburden materials, mine pit backfilling and grading, protection of
the hydrologic balance, surface drainage control, mine drainage and mine discharge control and treatment, and revegetation.
Although mining permits have stated expiration dates, SMCRA provides for a right of successive renewal. The cost of
obtaining surface mining permits can vary widely depending on the quantity and type of information that must be provided to
obtain the permits; however, the cost of obtaining a permit is usually between $1,000,000 and $5,000,000, and the cost of
obtaining a permit renewal is usually between $15,000 and $100,000.
The Abandoned Mine Land Fund, which is provided for by SMCRA, imposes a fee on certain coal mining operations. The
proceeds are intended to be used principally to reclaim mine lands closed prior to 1977. In addition, the Abandoned Mine Land
Fund also makes transfers annually to the United Mine Workers of America Combined Benefit Fund (the “Fund”), which
provides health care benefits to retired coal miners who are beneficiaries of the Fund. The 2021 Infrastructure Investment and
Jobs Act reauthorized the Abandoned Mine Land fee at a reduced rate. The fee for lignite coal was reduced from $0.08 per ton
to $0.064 per ton and for other surface-mined coal from $0.28 per ton to $0.224 per ton. These fees have been reauthorized until
the end of fiscal year 2035.
SMCRA establishes operational, reclamation and closure standards for surface coal mines. The Company accrues for the costs
of current mine disturbance and final mine closure, including the cost of treating mine water discharges, at mines where the
Company's subsidiaries hold the mining permit. These obligations are largely unfunded, with the exception of the final mine
closure costs for the Coyote Creek Mine, which are being funded throughout the production stage.
SMCRA stipulates compliance with many other major environmental programs, including the CAA and CWA. The U.S. Army
Corps of Engineers regulates activities affecting navigable waters, and the U.S. Bureau of Alcohol, Tobacco and Firearms
regulates the use of explosives for blasting. In addition, the U.S. Environmental Protection Agency (the “EPA”), the U.S. Army
Corps of Engineers and the OSMRE have engaged in a series of rulemakings and other administrative actions under the CWA
and other statutes that are directed at reducing the impact of coal mining operations on water bodies.
The Company does not believe there is any significant risk to the Company's subsidiaries ability to maintain its existing mining
permits or its ability to acquire future mining permits for its mines.
10
Clean Air Act and Affordable Clean Energy Rule ("ACE")
The process of burning coal can cause many compounds and impurities in the coal to be released into the air, including sulfur
dioxide, nitrogen oxides, mercury, particulates and other matter. The CAA and the corresponding state laws that extensively
regulate the emissions of materials into the air affect coal mining operations both directly and indirectly. Direct impacts on coal
mining operations occur through CAA permitting requirements and/or emission control requirements relating to air
contaminants, especially particulate matter. Indirect impacts on coal mining operations occur through regulation of the air
emissions of sulfur dioxide, nitrogen oxides, mercury, particulate matter and other compounds emitted by coal-fired power
plants. The EPA has promulgated or proposed regulations that impose tighter emission restrictions in a number of areas, some
of which are currently subject to litigation. The general effect of tighter restrictions is to reduce demand for coal. Ongoing
reduction in coal’s share of the capacity for power generation could have a material adverse effect on the Company’s business,
financial condition and results of operations.
States are required to submit to the EPA revisions to their state implementation plans ("SIPs") that demonstrate the manner in
which the states will attain national ambient air quality standards ("NAAQS") every time a NAAQS is issued or revised by the
EPA. The EPA has adopted NAAQS for several pollutants, which continue to be reviewed periodically for revisions. When the
EPA adopts new, more stringent NAAQS for a pollutant, some states have to change their existing SIPs. If a state fails to revise
its SIP and obtain EPA approval, the EPA may adopt regulations to effect the revision. Coal mining operations and coal-fired
power plants that emit particulate matter or other specified material are, therefore, affected by changes in the SIPs. Through this
process over the last few years, the EPA has reduced the NAAQS for particulate matter, ozone, and nitrogen oxides. The
Company's coal mining operations and power generation customers may be directly affected when the revisions to the SIPs are
made and incorporate new NAAQS for sulfur dioxide, nitrogen oxides, ozone and particulate matter. In March 2019, the EPA
published a final rule that retains the current primary (health-based) NAAQS for sulfur oxides (SOx) without revision. The
current primary standard is set at a level of 75 parts per billion, as the 99th percentile of daily maximum 1-hour SO2
concentrations, averaged over 3 years. In mid-2011, the EPA finalized the Cross-State Air Pollution Rule ("CSAPR") to address
interstate transport of pollutants. This affects states in the eastern half of the U.S. and Texas. This rule imposes additional
emission restrictions on coal-fired power plants to attain ozone and fine particulate NAAQS. The EPA began implementation
of the rule in 2015, when Phase I emission reductions in sulfur dioxide and nitrogen dioxide became effective. Phase II
reductions became effective in 2017. In 2016, the EPA mandated additional reductions in nitrogen oxide emissions. The U.S.
Court of Appeals for the District of Columbia Circuit ("D.C. Circuit") remanded the CSAPR Update to the EPA to address the
court’s holding that the rule unlawfully allows significant contribution to continue beyond downwind attainment deadlines. In
2018, the EPA finalized all remaining ozone designations to comply with the 2015 ozone air quality standards. The U.S. Court
of Appeals for the D.C. Circuit issued a per curium opinion rejecting various industry challenges to the EPA’s 2015 revisions to
the ozone NAAQS, including that the EPA was required to consider certain adverse effects and background ozone when setting
the standards. None of the power plants supplied by the Company are within non-attainment areas for ozone. In March 2021,
EPA finalized the “Revised Cross-State Air Pollution Rule” to address the remand of the CSAPR update. The final rule requires
no further obligations in states where the Company’s customers operate a power plant.
The CAA Acid Rain Control Provisions were promulgated as part of the CAA Amendments of 1990 in Title IV of the CAA
(“Acid Rain Program”). The Acid Rain Program required reductions of sulfur dioxide emissions from coal-fired power plants.
The Acid Rain Program is now a mature program, and the Company believes that any market impacts of the required controls
have likely been factored into the coal market.
The EPA promulgated a regional haze program designed to protect and to improve visibility at and around Class I Areas, which
are generally National Parks, National Wilderness Areas and International Parks. This program may restrict the construction of
new coal-fired power plants, the operation of which may impair visibility at and around the Class I Areas. Additionally, the
program requires certain existing coal-fired power plants to install additional control measures designed to limit haze-causing
emissions, such as sulfur dioxide, nitrogen oxide and particulate matter. States were required to submit Regional Haze SIPs to
the EPA in 2007; however, many states did not meet that deadline. In 2016, the EPA finalized revisions to the Regional Haze
Rule which addresses requirements for the second planning period. In September 2019, the EPA issued final regional haze
guidance that indicates that a re-evaluation of sources already subject to best available retrofit technologies ("BART") is likely
unnecessary. The guidance also encourages states to balance visibility benefits against other factors in selecting the measures
necessary to make “reasonable progress” toward natural visibility conditions. Finally, when comparing various control options
to determine which ones may be “cost-effective,” the final guidance recommends comparing cost to visibility benefits. In July
of 2021, the EPA released a memorandum to clarify the guidance issued in 2019. While this clarification memorandum
attempted to reverse some of the core conclusions made in the 2019 guidance, it was released after the air analyses to develop
individual SIPs had been completed and just prior to the SIP submittal deadline to the EPA, which was July 31, 2021. Many
SIP submittals were delayed due to emissions modeling and continue to be developed and scrutinized. SIPs will be sent to the
EPA for approval following both review by federal land managers of the National Park Service, the United States Fish and
11
Wildlife Service and the United States Forest Service and all corresponding public comment periods. See "Item 1A - “Risk
Factors” on page 20 for further discussion of the regional haze program.
Under the CAA, new and modified sources of air pollution must meet certain new source standards (the “New Source Review
Program”). In the late 1990s, the EPA filed lawsuits against owners of many coal-fired power plants in the eastern U.S. alleging
that the owners performed non-routine maintenance, causing increased emissions that should have triggered the application of
these new source standards. Some of these lawsuits have been settled with the owners agreeing to install additional emission
control devices in their coal-fired power plants. The EPA has clarified the process for evaluating whether the New Source
Review (“NSR”) permitting program would apply to proposed projects at existing air pollution sources. Under the NSR
program, before constructing a new stationary emission source or a modification of an existing major source, the source owner
or operator must determine whether the new source will emit or the modification will increase air emissions above certain
thresholds. The rule makes it clear that both emissions increases and decreases from a major modification at an existing source
are to be considered during Step 1 of the two-step NSR applicability test which is designed to determine if there is a “significant
emission increase”. In October 2021, the EPA denied a petition for reconsideration and administrative stay of the final rule;
however, the remaining litigation and the uncertainty around the NSR program rules could adversely impact demand for coal.
Any additional new controls may have an adverse impact on the demand for coal, which may have a material adverse effect on
the Company’s business, financial condition or results of operations.
Under the CAA, the EPA also adopts national emission standards for hazardous air pollutants. In December 2011, the EPA
adopted a final rule called the Mercury and Air Toxics Standard (“MATS”), which applies to new and existing coal-fired and
oil-fired units. This rule requires mercury emission reductions in fine particulates, which are being regulated as a surrogate for
certain metals.
The Company's power generation customers must incur substantial costs to control emissions to meet all of the CAA
requirements, including the requirements under MATS and the EPA's regional haze program. These costs raise the price of
coal-generated electricity, making coal-fired power less competitive with other sources of electricity, thereby reducing demand
for coal. If the Company's customers cannot offset the cost to control certain regulated pollutant emissions by lowering costs or
if the Company's customers elect to close coal-fired units, the Company’s business, financial condition and results of operations
could be materially adversely affected.
Global climate change continues to attract considerable attention in the United States. The U.S. Congress has considered
climate change legislation aimed at reducing greenhouse gas (“GHG”) emissions, particularly from coal combustion by power
plants. Enactment of laws and passage of regulations regarding GHG emissions by the U.S. or additional states, or other actions
to limit carbon dioxide emissions, such as opposition by environmental groups to expansion or modification of coal-fired power
plants, could result in electric generators switching from coal to other fuel sources.
The U.S. Congress continues to consider a variety of proposals to reduce GHG emissions from the combustion of coal and other
fuels. These proposals include emission taxes, emission reductions, including carbon tax and “cap-and-trade” programs, and
mandates or incentives to generate electricity by using renewable resources, such as wind or solar power. Some states have
established programs to reduce GHG emissions. Further, governmental agencies have been providing grants or other financial
incentives to entities developing or selling alternative energy sources with lower levels of GHG emissions, which may lead to
more competition from those entities.
The EPA introduced a GHG regulation program under the CAA by issuing a finding that the emission of six GHGs, including
carbon dioxide and methane, may reasonably be anticipated to endanger public health and welfare. Based on that finding, the
EPA published a New Source Performance Standard for greenhouse gases, applicable to certain new power plants. In 2019, the
EPA issued the Affordable Clean Energy ("ACE") Rule to reduce GHG emissions from existing electric generating units
("EGUs"). In contrast to the Clean Power Plan, the ACE rule limited "best system of emission reduction" ("BSER") to only
"inside the fenceline" heat rate improvement technologies or systems that can be applied at an affected coal-fired EGU. The
ACE rule was challenged by a suite of petitioners before the U.S. Circuit Court of Appeals, District of Columbia Circuit ("DC
Circuit") which subsequently ruled that the EPA erred when it rescinded the Clean Power Plan and they vacated the ACE rule.
In early 2021, the EPA issued an endangerment/significant contribution finding for carbon dioxide emissions from coal-fired
power plants. In addition, the DC Circuit court ruling was challenged by several parties, including the Company, and the
Supreme Court of the United States recently granted certiorari. The Supreme Court of the United States will hear the case in
February 2022. Depending on the outcome of the Supreme Court ruling, the EPA may draft a new rule to regulate carbon
dioxide emissions which, depending on the scope and applicability of the rule, may have a material adverse effect on the
Company’s business, financial condition or results of operations.
12
The U.S. has not implemented the 1992 Framework Convention on Global Climate Change (“Kyoto Protocol”), which became
effective for many countries on February 16, 2005. The Kyoto Protocol was intended to limit or reduce emissions of GHGs.
The U.S. has not ratified the emission targets of the Kyoto Protocol or any other GHG agreement. Though the U.S. has not
accepted these international GHG limiting treaties, numerous lawsuits and regulatory actions have been undertaken by states
and environmental groups to try to force controls on the emission of carbon dioxide; or to prevent the construction of new coal-
fired power plants.
As a successor to the Kyoto Protocol, in 2015, international negotiators finalized the Paris Agreement under the United Nations
Framework Convention on Climate Change (“Paris Agreement”). Unlike the Kyoto Protocol, the Paris Agreement has no
binding GHG reduction mandates on signatories. Participating countries only submit a description of their intended GHG
reductions, and provide periodic progress updates, with no penalties for not meeting their self-imposed targets. The Paris
Agreement also includes language stating that developed countries will provide financial assistance to help developing
countries meet their GHG targets and adapt to climate change, but there are no mandated contributions. In November 2020, the
United States formally withdrew from the Paris Agreement; however, the United States rejoined in February 2021. The
renegotiation and implementation of the Paris Agreement, or other international agreements, the regulations promulgated to
date by the EPA with respect to GHG emissions or the adoption of new legislation or regulations to control GHG emissions,
could have a materially adverse effect on the Company’s business, financial condition and results of operations.
Significant public opposition has also been raised with respect to the proposed construction of certain new coal-fired EGUs due
to the potential for increased air emissions. Such opposition, as well as any corporate or investor policies against coal-fired
EGUs or requiring disclosures related to global climate change, could also reduce the demand for the Company's coal or
marketability of NACCO stock. Further, policies limiting available financing for the development of new coal-fueled EGUs or
coal mines or the retrofitting of existing EGUs could adversely impact the global demand for coal in the future. The potential
impact on the Company of future laws, regulations or other policies or circumstances will depend upon the degree to which any
such laws, regulations or other policies or circumstances force electricity generators to diminish their reliance on coal as a fuel
source. In view of the significant uncertainty surrounding each of these factors, it is not possible for the Company to predict
reasonably the impact that any such laws, regulations or other policies may have on the Company's business, financial condition
and results of operations. However, such impacts could have a material adverse effect on the Company's business, financial
condition and results of operations.
The Company believes it has obtained all necessary permits under the CAA at all of its coal mining operations where it is
responsible for permitting and is in compliance with such permits.
Clean Water Act
The Clean Water Act ("CWA") affects coal mining operations by establishing in-stream water quality standards and treatment
standards for waste water discharge. Permits requiring regular monitoring, reporting and performance standards govern the
discharge of pollutants into water. Waters discharged from coal mines are required to meet these standards. These federal and
state requirements could require more costly water treatment and could materially adversely affect the Company’s business,
financial condition and results of operations.
The Company believes it has obtained all permits required under the CWA and corresponding state laws and is in compliance
with such permits. In many instances, mining operations require securing CWA authorization or a permit from the U.S. Army
Corps of Engineers for operations in waters of the United States. The U.S. Army Corps of Engineers and EPA jointly revised
the definition of a water of the United States ("WOTUS") in the June 2020 Navigable Water Protection Rule ("NWPR"). The
new definition was challenged in court and two court cases resulted in vacatur of the NWPR. In December 2021, the EPA and
COE released a draft “Step One” rule to redefine WOTUS by formally rescinding the NWPR and replacing it with a new
definition. If the new definition is promulgated as drafted, some of the Company's operations could incur additional costs to
mitigate streams and wetlands.
Bellaire is treating mine water drainage from coal refuse piles associated with two former underground coal mines in Ohio and
one former underground coal mine in Pennsylvania, and is treating mine water from a former underground coal mine in
Pennsylvania. Bellaire anticipates that it will need to continue these activities indefinitely. See Note 7 to the Consolidated
Financial Statements in this Form 10-K for further discussion of the Company's asset retirement obligations.
Bellaire was notified by the Pennsylvania Department of Environmental Protection ("DEP") during 2004 that in order to obtain
renewal of a permit, Bellaire would be required to establish a mine water treatment trust (the "Trust"). See Note 7 and Note 9 to
the Consolidated Financial Statements in this Form 10-K for further information on the Trust.
13
Resource Conservation and Recovery Act
The Resource Conservation and Recovery Act ("RCRA") affects coal mining operations by establishing requirements for the
treatment, storage and disposal of wastes, including hazardous wastes. Coal mine wastes, such as overburden and coal cleaning
wastes, currently are exempted from hazardous waste management. In December 2014, the EPA finalized a rule specifying
management standards for coal combustion residuals or coal ash ("CCRs") as a non-hazardous waste. In 2018, the EPA
finalized revisions to the 2014 regulations in response to litigation of the 2014 rule. One revision allows a state director (in a
state with an approved CCR permit program) or the EPA (where EPA is the permitting authority) to suspend groundwater
monitoring requirements if there is evidence that there is no potential for migration of hazardous constituents to the uppermost
aquifer during the active life of the unit and post closure care. The second revision allows issuance of technical certifications in
lieu of a professional engineer. In addition, the EPA revised the groundwater protection standards and extended the deadline for
some facilities that must close CCR units. In 2020, the EPA finalized additional changes to the CCR rule that classified all clay-
lined surface impoundments that receive CCR as unlined, which triggered a pond closure date of April 2021 for impoundments
that failed the aquifer location restriction. The EPA also established alternative deadlines to cease receipt of waste to include
new site-specific alternatives due to lack of capacity with a deadline to initiate closure no later than October 15, 2023 and a new
site-specific alternative due to permanent cessation of coal-fired boilers with two deadlines to complete closure: (a) no later
than October 17, 2023 for surface impoundments 40 acres or smaller; and (b) October 17, 2028 for surface impoundments
larger than 40 acres. This new rule may raise the cost for CCR disposal at coal-fired power plants, making them less
competitive, and/or result in early closure which could have an adverse impact on demand for coal.
The EPA rule exempts CCRs beneficially used at mine sites and reserves any regulation thereof to the OSMRE. The OSMRE
suspended all rulemaking actions on CCRs, but could re-initiate them in the future. The outcome of these rulemakings, and any
subsequent actions by EPA and OSMRE, could impact those Company operations that beneficially use CCRs. If the Company
were unable to beneficially use CCRs, its revenues for handling CCRs from its customers may decrease and its costs may
increase due to the purchase of alternative materials for beneficial uses.
National Environmental Policy Act
NEPA requires federal agencies to review the environmental impacts of their decisions and issue either an environmental
assessment or an environmental impact statement. There are certain actions associated with surface coal mining that may trigger
these types of assessments by federal agencies. When a NEPA action is required, the Company provides the required
information to the appropriate federal agency so that they may complete the environmental assessment. Historically, this
process has been lengthy and may take several years to complete. In July 2020, the White House Council on Environmental
Quality ("CEQ") issued a final rule updating the original NEPA regulations; however, it was immediately challenged by states
and non-governmental organizations. In October 2021, the CEQ issued a new draft rule rescinding many of the revisions from
2020 update. If finalized as drafted, the revised NEPA regulations could adversely affect the Company’s ability to secure
necessary permits.
Regulation of the Oil and Natural Gas Industry
The oil and natural gas industry is extensively regulated by numerous federal, state and local authorities. Legislation affecting
the oil and natural gas industry is under constant review for amendment or expansion, frequently increasing the regulatory
burden. Also, numerous departments and agencies, both federal and state, are authorized by statute to issue rules and
regulations that are binding on the oil and natural gas industry and its individual members, some of which carry substantial
penalties for failure to comply. Although the regulatory burden on the oil and natural gas industry increases the cost of doing
business, these burdens generally do not affect the Company any differently or to any greater or lesser extent than they affect
other companies in the industry with similar types, quantities and locations of production.
The availability, terms and cost of transportation significantly affect sales of oil and natural gas. The interstate transportation of
oil and natural gas and the sale for resale of natural gas is subject to federal regulation, including regulation of the terms,
conditions and rates for interstate transportation, storage and various other matters, primarily by the Federal Energy Regulatory
Commission (“FERC”). Federal and state regulations govern the price and terms for access to oil and natural gas pipeline
transportation. FERC’s regulations for interstate oil and natural gas transmission in some circumstances may also affect the
intrastate transportation of oil and natural gas.
Although oil and natural gas prices are currently unregulated, Congress historically has been active in the area of oil and natural
gas regulation. The Company cannot predict whether new legislation to regulate oil and natural gas might be proposed, what
proposals, if any, might be enacted by Congress or the various state legislatures, and what effect, if any, the proposals might
have on the Minerals Management segment. Sales of crude oil, condensate and natural gas liquids ("NGLs") are not currently
regulated and are made at market prices.
14
Environmental Matters
Oil and natural gas exploration, development and production operations are subject to stringent laws and regulations governing
the discharge of materials into the environment or otherwise relating to protection of the environment or occupational health
and safety. These laws and regulations have the potential to impact production on the Company’s mineral interests, which could
materially adversely affect the Minerals Management segment. Numerous federal, state and local governmental agencies, such
as the EPA, issue regulations that often require difficult and costly compliance measures that carry substantial administrative,
civil and criminal penalties and may result in injunctive obligations for non-compliance. These laws and regulations may
require the acquisition of a permit before drilling commences, restrict the types, quantities and concentrations of various
substances that can be released into the environment in connection with drilling and production activities, limit or prohibit
construction or drilling activities on certain lands lying within wilderness, wetlands, ecologically sensitive and other protected
areas, require action to prevent or remediate pollution from current or former operations, such as plugging abandoned wells or
closing earthen pits, result in the suspension or revocation of necessary permits, licenses and authorizations, require that
additional pollution controls be installed and impose substantial liabilities for pollution resulting from operations. The strict,
joint and several liability nature of such laws and regulations could impose liability upon the operators on the Company’s
mineral interests, regardless of fault. Moreover, it is not uncommon for neighboring landowners and other third parties to file
claims for personal injury and property damage allegedly caused by the release of hazardous substances, hydrocarbons or other
waste products into the environment. Changes in environmental laws and regulations occur frequently, and any changes that
result in more stringent and costly pollution control or waste handling, storage, transport, disposal or cleanup requirements
could materially adversely affect the Minerals Management segment.
Drilling and Production
The operations of the Company’s third-party lessees are subject to various types of regulation at the federal, state and local
level. These types of regulation include requiring permits for the drilling of wells, drilling bonds and reports concerning
operations. The states, and some counties and municipalities, in which the Company has mineral interests also regulate one or
more of the following:
•
•
•
•
•
•
•
the location of wells;
the method of drilling and casing wells;
the timing of construction or drilling activities, including seasonal wildlife closures;
the rates of production or "allowables";
the surface use and restoration of properties upon which wells are drilled;
the plugging and abandoning of wells; and
notice to, and consultation with, surface owners and other third parties.
State laws regulate the size and shape of drilling and spacing units or proration units governing the pooling of oil and natural
gas properties. Some states allow forced pooling or integration of tracts to facilitate exploration while other states rely on
voluntary pooling of lands and leases. In some instances, forced pooling or unitization may be implemented by third parties and
may reduce the Company’s interest in the unitized properties. In addition, state conservation laws establish maximum rates of
production from oil and natural gas wells, generally prohibit the venting or flaring of natural gas and impose requirements
regarding the ratability of production. These laws and regulations may limit the amount of oil and natural gas that the lessees of
the Company’s mineral interests can produce from existing wells or limit the number of wells or the locations at which
operators can drill. Moreover, each state generally imposes a production or severance tax with respect to the production and sale
of oil, natural gas and NGLs within its jurisdiction. States do not regulate wellhead prices or engage in other similar direct
regulation, but the effect of any future regulations could have a material effect on the Minerals Management segment. The
effect of such future regulations may be to limit the amounts of oil and natural gas that may be produced from the Company’s
mineral interests, negatively affect the economics of production from these wells or to limit the number of locations operators
can drill.
Federal, state and local regulations provide detailed requirements for the abandonment of wells, closure or decommissioning of
production facilities and pipelines and for site restoration in areas where the operators of the acreage underlying the Company's
mineral and royalty interests operate. The U.S. Army Corps of Engineers and many other state and local authorities also have
regulations for plugging and abandonment, decommissioning and site restoration. Although the U.S. Army Corps of Engineers
does not require bonds or other financial assurances, some state agencies and municipalities do have such requirements.
Regulation of Hydraulic Fracturing
Hydraulic fracturing is an important common practice that is used to stimulate production of hydrocarbons, particularly natural
gas, from tight formations, including shales. The process involves the injection of water, sand and chemicals under pressure into
formations to fracture the surrounding rock and stimulate production. The CWA regulates the underground injection of
substances through the Underground Injection Control (“UIC”) program. Hydraulic fracturing generally is exempt from
regulation under the UIC program, and the hydraulic fracturing process is typically regulated by state oil and gas commissions.
15
However, in recent years efforts have been made to regulate hydraulic fracturing at the federal level. In addition, the Biden
administration has signaled the intent to stop hydraulic fracturing on federal land.
In addition, several states, including Texas, have adopted, or are considering adopting, regulations that could restrict or prohibit
hydraulic fracturing in certain circumstances and/or require the disclosure of the composition of hydraulic fracturing fluids. The
Texas Legislature previously adopted legislation requiring oil and gas operators to publicly disclose the chemicals used in the
hydraulic fracturing process, effective as of September 1, 2011. The Texas Railroad Commission subsequently adopted rules
and regulations implementing this legislation that apply to all wells for which the Railroad Commission issues an initial drilling
permit. This law requires that the well operator disclose the list of chemical ingredients subject to the requirements of the
Occupational Safety and Health Act for disclosure on an internet website and also file the list of chemicals with the Texas
Railroad Commission with the well completion report. The total volume of water used to hydraulically fracture a well must also
be disclosed to the public and filed with the Texas Railroad Commission. Further, in May 2013, the Texas Railroad
Commission issued a “well integrity rule,” which updates the requirements for drilling, putting pipe down, and cementing
wells. The rule also includes new testing and reporting requirements, such as: (i) the requirement to submit cementing reports
after well completion or after cessation of drilling, whichever is later; and (ii) the imposition of additional testing on wells less
than 1,000 feet below usable groundwater. The well integrity rule took effect in January 2014. Local governments also may
seek to adopt ordinances within their jurisdictions regulating the time, place and manner of drilling activities in general or
hydraulic fracturing activities in particular or prohibit the performance of well drilling in general or hydraulic fracturing in
particular.
There has been increasing public controversy regarding hydraulic fracturing with regard to the use of fracturing fluids, impacts
on drinking water supplies, use of water and the potential for impacts to surface water, groundwater and the environment
generally. A number of lawsuits and enforcement actions have been initiated across the country implicating hydraulic fracturing
practices. If new laws or regulations that significantly restrict hydraulic fracturing are adopted, such laws could make it more
difficult or costly to perform fracturing to stimulate production from tight formations as well as make it easier for third parties
opposing the hydraulic fracturing process to initiate legal proceedings based on allegations that specific chemicals used in the
fracturing process could adversely affect groundwater. In addition, if hydraulic fracturing is further regulated at the federal or
state level, fracturing activities could become subject to additional permitting and financial assurance requirements, more
stringent construction specifications, increased monitoring, reporting and recordkeeping obligations, plugging and abandonment
requirements and also to attendant permitting delays and potential increases in costs. Such legislative or regulatory changes
could cause operators of the operation on the acreage underlying the Company’s mineral interests to incur substantial
compliance costs, and compliance or the consequences of any failure to comply by operators could have a material adverse
effect on the Minerals Management segment.
In addition, hydraulic fracturing operations require the use of a significant amount of water, and the inability of the operators of
the acreage underlying the Company’s mineral interests to locate sufficient amounts of water or dispose of or recycle water
used in their drilling and production operations, could adversely impact their operations. Moreover, new environmental
initiatives and regulations could include restrictions on the ability to conduct certain operations such as hydraulic fracturing or
disposal of waste, including, but not limited to, produced water, drilling fluids and other wastes associated with the
development or production of natural gas.
In some instances, the operation of underground injection wells has been alleged to cause earthquakes. Such issues have
sometimes led to orders prohibiting continued injection or the suspension of drilling in certain wells identified as possible
sources of seismic activity. Such concerns also have resulted in stricter regulatory requirements in some jurisdictions relating to
the location and operation of underground injection wells. Future orders or regulations addressing concerns about seismic
activity from well injection could affect operations on the acreage underlying the Company’s mineral interests.
Endangered Species Act
The Endangered Species Act (“ESA”) and analogous state laws restrict activities that may affect endangered or threatened
species or their habitats. Pursuant to a settlement with environmental groups, the U.S. Fish and Wildlife Service (“USFWS”)
was required to determine whether over 250 species required listing as threatened or endangered under the ESA. USFWS has
not yet completed its review, but the potential remains for new species to be listed under the ESA. Some of the Company’s
properties or mineral interests may be located in areas that are or may be designated as habitats for endangered or threatened
species, and previously unprotected species may later be designated as threatened or endangered in areas where the Company
holds interests. For example, recently, there have been renewed calls to review protections currently in place for the Dunes
Sagebrush Lizard, whose habitat includes portions of the Permian Basin, and to reconsider listing the species under the ESA.
Likewise, there have been calls to review protections in place for the Greater Sage Grouse, which can be found across a large
swath of the northwestern United States in oil and gas producing states. The listing of either of these species, or any others, in
areas where the Company holds minerals interests could cause lessees to incur increased costs arising from species protection
16
measures, delay the completion of exploration and production activities, and/or result in limitations on operating activities that
could have an adverse impact the Minerals Management segment.
Natural Gas Sales and Transportation
Historically, federal legislation and regulatory controls have affected the price and marketing of natural gas. FERC has
jurisdiction over the transportation and sale for resale of natural gas in interstate commerce by natural gas companies under the
Natural Gas Act of 1938 (“NGA”) and the Natural Gas Policy Act of 1978. Since 1978, various federal laws have been enacted
which have resulted in the complete removal of all price and non-price controls for sales of domestic natural gas sold in “first
sales.” Under the Energy Policy Act of 2005, FERC has substantial enforcement authority to prohibit the manipulation of
natural gas markets and enforce its rules and orders, including the ability to assess substantial civil penalties.
FERC also regulates interstate natural gas transportation rates and service conditions and establishes the terms under which
operators may use interstate natural gas pipeline capacity, which affects the marketing of natural gas that operators produce, as
well as the revenues operators receive for sales of natural gas and release of natural gas pipeline capacity. Commencing in
1985, FERC promulgated a series of orders, regulations and rule makings that significantly fostered competition in the business
of transporting and marketing gas. Today, interstate pipeline companies are required to provide nondiscriminatory
transportation services to producers, marketers and other shippers, regardless of whether such shippers are affiliated with an
interstate pipeline company. FERC’s initiatives have led to the development of a competitive, open access market for natural
gas purchases and sales that permits all purchasers of natural gas to buy gas directly from third-party sellers other than
pipelines. However, the natural gas industry historically has been very heavily regulated; therefore, the Company cannot
guarantee that the less stringent regulatory approach currently pursued by FERC and Congress will continue indefinitely into
the future nor can the Company determine what effect, if any, future regulatory changes might have on natural gas-related
activities.
Under FERC’s current regulatory regime, transmission services must be provided on an open-access, nondiscriminatory basis at
cost-based rates or at market-based rates if the transportation market at issue is sufficiently competitive. Gathering service,
which occurs upstream of jurisdictional transmission services, is regulated by the states onshore and in-state waters. Section
1(b) of the NGA exempts natural gas gathering facilities from regulation by FERC as a natural gas company under the NGA.
Although its policy is still in flux, FERC has in the past reclassified certain jurisdictional transmission facilities as non-
jurisdictional gathering facilities, which has the tendency to increase operators’ costs of transporting gas to point-of-sale
locations.
Oil Sales and Transportation
Sales of crude oil, condensate and natural gas liquids are not currently regulated and are made at negotiated prices.
Nevertheless, Congress could reenact price controls in the future.
Crude oil sales are affected by the availability, terms and cost of transportation. The transportation of oil in common carrier
pipelines is also subject to rate regulation. FERC regulates interstate oil pipeline transportation rates under the Interstate
Commerce Act and intrastate oil pipeline transportation rates are subject to regulation by state regulatory commissions. The
basis for intrastate oil pipeline regulation, and the degree of regulatory oversight and scrutiny given to intrastate oil pipeline
rates, varies from state to state. Insofar as effective interstate and intrastate rates are equally applicable to all comparable
shippers, the Company believes that the regulation of oil transportation rates will not affect its operations in any materially
different way than such regulation will affect the operations of competitors.
Further, interstate and intrastate common carrier oil pipelines must provide service on a non-discriminatory basis. Under this
open access standard, common carriers must offer service to all shippers requesting service on the same terms and under the
same rates. When oil pipelines operate at full capacity, access is governed by portioning provisions set forth in the pipelines’
published tariffs. Accordingly, the Company believes that access to oil pipeline transportation services generally will be
available to its operators to the same extent as to the Company or its competitors.
17
State Regulation
Texas regulates the drilling for, and the production, gathering and sale of, oil and natural gas, including imposing severance
taxes and requirements for obtaining drilling permits. Texas currently imposes a 4.6% severance tax on the market value of oil
production and a 7.5% severance tax on the market value of natural gas production. States also regulate the method of
developing new fields, the spacing and operation of wells and the prevention of waste of oil and natural gas resources. States
may regulate rates of production and may establish maximum daily production allowable from oil and natural gas wells based
on market demand or resource conservation, or both. States do not regulate wellhead prices or engage in other similar direct
economic regulation, but the Company cannot be certain that they will not do so in the future. The effect of these regulations
may be to limit the amount of oil and natural gas that may be produced from wells drilled by third-party lessee's and to limit the
number of wells or locations the Company's third-party lessee operators can drill.
The petroleum industry is also subject to compliance with various other federal, state and local regulations and laws. Some of
those laws relate to resource conservation and equal employment opportunity. The Company does not believe that compliance
with these laws will have a material adverse effect on its results of operations or financial condition.
Comprehensive Environmental Response, Compensation and Liability Act
The Comprehensive Environmental Response, Compensation and Liability Act ("CERCLA") and similar state laws create
liabilities for the investigation and remediation of releases of hazardous substances into the environment and for damages to
natural resources. The Company must also comply with reporting requirements under the Emergency Planning and Community
Right-to-Know Act and the Toxic Substances Control Act.
From time to time, the Company has been the subject of administrative proceedings, litigation and investigations relating to
environmental matters.
The extent of the liability and the cost of complying with environmental laws cannot be predicted with certainty due to many
factors, including the lack of specific information available with respect to many sites, the potential for new or changed laws
and regulations, the development of new remediation technologies and the uncertainty regarding the timing of work with
respect to particular sites. As a result, the Company may incur material liabilities or costs related to environmental matters in
the future, and such environmental liabilities or costs could materially and adversely affect the Company’s results of operations
and financial condition. In addition, there can be no assurance that changes in laws or regulations would not affect the manner
in which the Company is required to conduct its operations.
INFORMATION ABOUT OUR EXECUTIVE OFFICERS
The following tables set forth as of March 1, 2022 the name, age, current position and principal occupation and employment
during the past five years of the Company’s executive officers. There exists no arrangement or understanding between any
executive officer and any other person pursuant to which such executive officer was selected.
18
EXECUTIVE OFFICERS OF THE COMPANY
Name
J.C. Butler, Jr.
Age Current Position
61
President and Chief Executive Officer of NACCO (from
September 2017) and President and Chief Executive
Officer of NACoal (from prior to 2017)
Other Positions
From prior to 2017 to September 2017, Senior Vice
President - Finance, Treasurer and Chief Administrative
Officer of NACCO. From prior to 2017 to September
2017, Assistant Secretary of Hamilton Beach Brands
("HBB") and Kitchen Collection ("KC").
Matthew J. Dilluvio
32 Associate Counsel and Assistant Secretary of NACCO
and NACoal (from June 2019)
From prior to 2017 to May 2019, Associate, Sidley
Austin LLP (law firm).
Elizabeth I. Loveman
52 Vice President and Controller and Principal Financial
Officer (from prior to 2017)
John D. Neumann
46 Vice President, General Counsel and Secretary of
NACCO, Vice President, General Counsel and Secretary
of NACoal (from prior to 2017)
From prior to 2017 to September 2017, Assistant
Secretary of HBB and KC.
Miles B. Haberer
55 Associate General Counsel of NACCO (from prior to
2017), Associate General Counsel, Assistant Secretary of
NACoal (from prior to 2017) and President, North
American Coal Royalty Company (an NACoal
subsidiary) (from prior to 2017)
Sarah E. Fry
46 Associate General Counsel and Assistant Secretary of
NACCO (from May 2017), Associate General Counsel
and Assistant Secretary of NACoal (from May 2017)
From prior to 2017 to April 2017, Senior Counsel, Locke
Lord (law firm).
Thomas A. Maxwell
44 Vice President - Financial Planning and Analysis and
Treasurer (from September 2017)
From prior to 2017 to September 2017, Director of
Financial Planning and Analysis and Assistant Treasurer.
PRINCIPAL OFFICERS OF THE COMPANY’S SUBSIDIARIES
Name
Eric S. Anderson
Age Current Position
46
President - Mitigation Resources (from March 2017)
Other Positions
From prior to 2017 to February 2017, Environmental
Manager, The Sabine Mining Company (an NACoal
subsidiary).
Philip N. Berry
54
President - NAMining (from prior to 2017)
Eric A. Dale
47 Treasurer and Senior Director, Financial Planning and
Analysis, of NACoal (from January 2017)
Carroll L. Dewing
65 Vice President - Operations of NACoal (from January
2017)
Andrew B. Hart
43 Controller of NACoal (from September 2019)
From November 2017 to August 2019, Assistant
Controller of NACoal. From prior to 2017 to October
2017, Assistant Controller at Rowan Companies, plc.
Brian M. Larson
38
President - Catapult Mineral Partners, LLC (from May
2019) and Director - Oil and Gas Development (from
April 2019)
From prior to 2017 to March 2019, Engineer at Pioneer
Natural Resources.
J. Patrick Sullivan, Jr.
63 Vice President and Chief Financial Officer of NACoal
(from prior to 2017)
19
Item 1A. RISK FACTORS
The Company operates in a rapidly changing environment that involves a number of risks. The following discussion highlights
some of these risks and others are discussed elsewhere in this report. These and other risks could materially and adversely affect
the Company’s business, financial condition, operating results or cash flows. The following risk factors are not an exhaustive
list of the risks associated with the Company’s business. New factors may emerge or changes to these risks could occur that
could materially affect the Company’s business.
Risks related to the Coal Mining segment
Termination of or default under long-term mining contracts could adversely affect the Company's business, financial
condition, results of operation and cash flows.
Substantially all of the Coal Mining segment's profits are derived from long-term mining contracts. Although the Company has
long-term contracts, numerous regulatory authorities, along with well-funded political and environmental activist groups, are
devoting substantial resources to anti-coal activities to minimize or eliminate the use of coal as a source of electricity
generation. Any customer's premature facility closure, including as discussed in “Item 1. Business — Business Developments"
on page 2 or a result of GRE’s failure to complete the sale of Coal Creek Station and the adjacent high-voltage direct current
transmission line to Rainbow Energy and its affiliates currently anticipated to close in the second quarter of 2022, could have a
material adverse effect on the Company’s business, financial condition and results of operations.
State implementation of the EPA’s Regional Haze Rule (“RHR”) could require Coyote Creek’s customers to incur significant
new costs at the Coyote Station power plant, which could, dependent on determinations by state regulatory commissions
regarding approval to recover such costs from the customers of Coyote Creek’s customer, negatively impact Coyote Creek’s
customers’ net income, financial position and cash flows. The Company understands that the North Dakota Department of
Environmental Quality (“NDDEQ”) could require sources subject to RHR Round 2 reasonable progress determinations,
including Coyote Station, to undertake emissions control measures. The emissions modeling conducted for the combined
western state agencies affected by the RHR was delayed and has subsequently delayed the NDDEQ state implementation plan
process. Therefore, the NDDEQ's state implementation plan, which was due to the EPA by July 2021, is anticipated to be
submitted to EPA early in 2022. If NDDEQ requires significant emissions controls at Coyote Station power plant by December
31, 2028, it may not be economically feasible for Coyote Creek's customers to invest in such equipment and an early retirement
of Coyote Station and the Coyote Creek mine could be necessary.
The Company could be negatively impacted by the decisions of Coyote Creek's customers. In September 2021, one of Coyote
Creek's customers, Otter Tail Power Company, filed its 2022 Integrated Resource Plan in Minnesota and North Dakota which
included its intent to start the process of withdrawal from its 35 percent ownership interest in Coyote Station power plant with
an anticipated exit from the plant by December 31, 2028.
Under certain circumstances of default or termination of Coyote Creek’s Lignite Sales Agreement (“LSA”), the Company
would be obligated for payment of a "make-whole" amount to Coyote Creek’s third-party lenders. The “make-whole” amount is
based on the excess, if any, of the discounted value of the remaining scheduled debt payments over the principal amount. In
addition, in the event Coyote Creek’s LSA is terminated on or after January 1, 2024 by Coyote Creek’s customers, the
Company is obligated to purchase Coyote Creek’s dragline and rolling stock for the then net book value of those assets. Any
decision by Coyote Creek’s customers to reduce operations or prematurely close the Coyote Creek mine would have a material
adverse effect on the Company’s results of operations, financial position and cash flows.
The loss of, or significant reduction in, purchases by NACCO's coal customers could adversely affect the Company's
business, financial condition, results of operation and cash flows.
For the year ended December 31, 2021, the Coal Mining segment derived approximately 68% of earnings of unconsolidated
operations from two customers, Basin Electric and GRE. There are inherent risks whenever a significant percentage of total
earnings are concentrated with a limited number of customers. Earnings from the Coal Mining segment's customers may
fluctuate from time to time based on numerous factors, including market conditions and the realignment of customers' power
generation portfolios that reduce the electric power generated from coal, which may be outside of the Company's control. If any
of the Coal Mining segment's customers experience declining demand due to market, economic, regulatory or competitive
conditions, it could have an adverse effect on the Company's profitability, cash flows and financial position. In addition, if any
customers were to significantly reduce or eliminate their purchases of coal from us or if the Company is unable to renew
expiring long-term sales agreements with existing customers or enter into new supply agreements, the Company's business,
financial condition, results of operations and cash flows could be adversely affected. See “Item 1. Business — Business
20
Developments" on page 2 in this Form 10-K for further discussion.
MLMC is subject to risks associated with its capital investment, operating and equipment costs, growing use of
alternative generation that competes with coal fired generation, changes in customer demand and inflationary
adjustments.
The profitability of MLMC is subject to the risk of loss of investment in this operation, increases in the cost of mining, changes
in customer demand, growing competition from alternative power generation that competes with coal-fired generation and the
emergence of adverse mining conditions. At MLMC, the costs of mining operations are not reimbursed by MLMC's customer.
As such, increased costs at MLMC or decreased revenues could materially reduce the Company's profitability. Any reduction in
customer demand at MLMC, including reductions related to reduced mechanical availability of the customer’s power plant,
would adversely affect the Company's operating results and could result in significant impairments. MLMC has approximately
$136 million of long-lived assets, including property, plant and equipment and a coal supply agreement intangible asset, which
are subject to periodic impairment analysis and review. Identifying and assessing whether impairment indicators exist, or if
events or changes in circumstances have occurred, including assumptions about future power plant dispatch levels, changes in
operating costs and other factors that impact anticipated revenue and customer demand, requires significant judgment. Actual
future operating results could differ significantly from these estimates, which may result in an impairment charge in a future
period, which could have a substantial impact on the Company’s results of operations.
MLMC sells lignite at contractually agreed upon prices which are subject to changes in the level of established indices over
time. As diesel fuel is heavily weighted among the indices used to determine the coal sales price, fluctuations in diesel fuel
prices can result in significant fluctuations in earnings at MLMC.
MLMC delivers coal to the Red Hills Power Plant in Ackerman, Mississippi. The Red Hills Power Plant supplies electricity to
TVA under a long-term PPA. MLMC’s contract with its customer runs through 2032. TVA’s power portfolio includes coal,
nuclear, hydroelectric, natural gas and renewables. In 2019, TVA published its updated Integrated Resource Plan, which
indicates plans to increase its reliance on solar power. A decrease in the number of days TVA dispatches the Red Hills Power
Plant would reduce MLMC's customer's demand for coal. The decision of which power plants to dispatch is determined by
TVA.
Choctaw Generation Limited Partnership ("CGLP") leases the Red Hills Power Plant from a Southern Company subsidiary
pursuant to a leveraged lease arrangement. CGLP's ability to make required payments to the Southern Company subsidiary is
dependent on the operational performance of the Red Hills Power Plant. During 2020, Southern Company revised the estimated
cash flows to be received under the leveraged lease which resulted in a full impairment of the lease investment. If any future
lease payment is not paid in full, the Southern Company subsidiary may be unable to make its corresponding payment to the
holders of the underlying non-recourse debt related to the Red Hills Power Plant. Failure to make the required payment to the
debtholders could represent an event of default that would give the debtholders the right to foreclose on, and take ownership of,
the Red Hills Power Plant from the Southern Company subsidiary. A foreclosure of the Red Hills Power Plant could have a
material adverse effect on MLMC's financial condition, results of operations and cash flows. Southern Company publicly
disclosed that all required lease payments have been paid in full through December 31, 2021
Similar to the Company's unconsolidated mines, all production costs at MLMC are capitalized into inventory and recognized in
cost of sales as tons are delivered. In periods of limited or no deliveries, MLMC may be required to reduce its inventory
carrying value using the lower of cost and net realizable value approach, which could adversely affect MLMC’s results of
operations.
Changes in customer demand for any reason, including, but not limited to, reduced mechanical availability of the customer’s
power plant, dispatch of power generated by other energy sources ahead of coal, fluctuations in demand due to unanticipated
weather conditions, regulations or comparable policies which may promote planned and unplanned outages at the Red Hills
Power Plant, economic conditions, including an economic slowdown and a corresponding decline in the use of electricity,
governmental regulations and inflationary adjustments could have a material adverse effect on MLMC's financial condition,
results of operations and cash flows.
The Coal Mining segment's Unconsolidated Subsidiaries are subject to risks created by changes in customer demand
and inflationary adjustments.
The contracts with the Unconsolidated Subsidiaries' customers are primarily based on a "management fee" approach, whereby
compensation includes reimbursement of all operating costs, plus a fee based on the amount of coal delivered. The fees earned
adjust over time in line with various indices which reflect general U.S. inflation rates. During the production stage, the
21
Unconsolidated Subsidiaries' customers pay the Company its agreed upon fee only for the coal delivered to them for
consumption or use. As a result, reduced coal usage by customers for any reason, including, but not limited to, fluctuations in
demand due to unanticipated weather conditions, scheduled and unscheduled outages at the Coal Mining segment's customers'
facilities, unplanned equipment failures, economic conditions or governmental regulations or comparable policies which may
promote dispatch of power generated by renewables, such as wind or solar, and the realignment of customers' power generation
portfolios that reduce the electric power generated from coal could have a material adverse effect on the Company's results of
operations. Because of the contractual price formulas for the management fees at these Unconsolidated Subsidiaries, the
profitability of these operations is also subject to fluctuations in inflationary adjustments (or lack thereof) that can impact the
agreed upon management fees. These factors could materially reduce the Company's profitability.
Changes in coal consumption patterns of U.S. electric power generators could adversely affect the Company's
profitability.
The amount of coal consumed by the electric power generation industry is affected by general economic conditions; overall
demand for electricity; availability of transmission; competition from alternative fuel sources for power generation, such as
natural gas, nuclear, hydroelectric, wind and solar power, and the location, availability, quality and price of those alternative
fuel sources; environmental and other governmental regulations, including those impacting coal-fired power plants; and energy
conservation efforts and related governmental policies.
Changes in the utility industry that affect NACCO's customers could also adversely affect the Company. The increased
availability of renewable energy sources has contributed to a reduction in demand for coal-fired electric power generation.
Competition from natural gas-fired plants that are relatively more efficient, less expensive to construct and less difficult to
permit than coal-fired plants has the most potential to continue to displace a significant amount of coal-fired electric power
generation in the near term. Federal and state mandates for increased use of electricity derived from renewable energy sources
have also adversely affected demand for coal-fired electric power generation. Such mandates make alternative fuel sources
more competitive with coal-fired electric power generation.
Changes in federal and state mandates that would include an acceleration in the use of electricity derived from renewable
energy sources could result in a decrease in coal consumption by the electric power generation industry and the Company’s
customers.
Certain of the Coal Mining segment’s customers, including MLMC's customer, benefit or have benefited from a tax credit
under Section 45 of the Internal Revenue Code. The benefit results in a reduction to the cost of coal-fired electric power
generation. The elimination or expiration of the Section 45 tax credit would increase the cost of the coal-fired electric power
generation from these facilities and could result in the power these facilities produce being less economical than other sources
of power generation, which could reduce demand and result in a decrease in coal consumption.
Any of these risks could result in a decrease in coal consumption by the Company’s customers and could have a material
adverse effect on the Company’s business, financial condition and results of operations.
Government regulations could impose costly requirements on the Company and its customers.
The coal mining industry and the electric generation industry are subject to extensive regulation by federal, state and local
authorities on matters concerning the health and safety of employees, land use, stream and wetland protection, permit and
licensing requirements, air and water quality standards, plant and wildlife protection, reclamation and restoration of mining
properties after mining, the discharge of GHGs and other materials into the environment, surface subsidence from underground
mining and the effects that mining has on groundwater quality and availability. Legislation mandating certain benefits for
current and retired coal miners also affects the industry. Mining operations require numerous governmental and regulatory
permits and approvals. The Company is required to prepare and present to federal, state or local authorities data pertaining to
the impact the production and combustion of coal may have upon the environment. The public, including non-governmental
organizations, opposition groups and individuals, have statutory rights to comment upon and submit objections to requested
permits and approvals and to legally challenge certain permits subsequent to their issuance. Compliance with these
requirements is costly and time-consuming and may delay commencement or continuation of development or production. New
legislation and/or regulations and orders may materially adversely affect the Company's mining operations or its cost structure,
or its customers. All of these factors could significantly reduce the Company's profitability. See “Item 1. Business —
Government Regulation" on page 9 in this Form 10-K for further discussion.
22
The Company is subject to burdensome federal and state mining regulations and the assumptions underlying the
Company's reclamation and mine closure obligations could be materially inaccurate.
Federal and state statutes require the Company to restore mine property in accordance with specified standards and an approved
reclamation plan, and require that the Company obtain and periodically renew permits for mining operations. Regulations
require the Company to incur the cost of reclaiming current mine disturbance at operations where the Company holds the
mining permit. Estimates of the Company's total reclamation and mine closing liabilities are based upon permit requirements
and the Company's engineering expertise related to these requirements. While management regularly reviews the estimated
reclamation liabilities and believes that appropriate accruals have been recorded for all expected reclamation and other costs
associated with closed mines, the estimate can change significantly if actual costs vary from assumptions or if governmental
regulations change significantly. Such changes could have a material adverse effect on the Company’s business and could
significantly reduce its profitability.
The Clean Air Act ("CAA") could reduce the demand for coal.
The process of burning coal can cause many compounds and impurities in the coal to be released into the air, including carbon
dioxide, sulfur dioxide, nitrogen oxides, mercury, particulates and other matter. The CAA and the corresponding state laws that
extensively regulate the emissions of materials into the air affect coal mining operations both directly and indirectly. Direct
impacts on coal mining operations occur through CAA permitting requirements and/or emission control requirements relating
to air contaminants, especially particulate matter. Indirect impacts on coal mining operations occur through regulation of the air
emissions of carbon dioxide, sulfur dioxide, nitrogen oxides, mercury, particulate matter and other compounds emitted by coal-
fired power plants. The EPA has discussed issuing or issued regulations that impose tighter emission restrictions on a number of
these compounds, some of which are currently subject to litigation. The general effect of tighter restrictions is to reduce demand
for coal. A reduction in coal’s share of the capacity for power generation could have a material adverse effect on the
Company’s business, financial condition and results of operations. See “Item 1. Business — Government Regulation" on page 9
in this Form 10-K for further discussion.
The Coal Mining segment's customers' operations require significant capital expenditures.
Maintaining and installing environmental controls on power plants requires significant capital expenditures. Any delay or
reduction in making capital expenditures to maintain or upgrade coal-fired power plants by the Coal Segment's customers,
principally electric utilities, could result in an increase in outage days and a corresponding decrease in coal consumption. A
decrease in coal consumption could have a material adverse effect on the Coal Mining segment's financial condition, results of
operations and cash flows.
Mining operations are vulnerable to weather and other conditions that are beyond the Company's control.
Many conditions beyond the Company's control can decrease the delivery, and therefore the use, of coal to the Company's
customers. These conditions include weather, pandemics, adverse mining conditions, unexpected maintenance problems and
shortages of replacement parts, any of which could significantly reduce the Company's profitability.
The Company faces numerous uncertainties in estimating economically recoverable reserves and resources, and
inaccuracies in estimates could result in lower than expected revenues, higher than expected costs and decreased
profitability.
Information concerning the Company's mining operations in "Item 2 - Properties on page 31" has been prepared in accordance
with the requirements of subpart 1300 of Regulation S-K, which first became applicable to us for the fiscal year ended
December 31, 2021. A mineral is economically recoverable when the price at which it can be sold exceeds the costs and
expenses of mining, processing and selling the mineral. Forecasts of NACCO's future performance are based on, among other
things, estimates of mineral reserves and resources. Mineral reserve and resource estimates of the remaining tons of coal in the
Company's operational mines and other mining properties are based on many factors, including engineering, economic and
geological data assembled and analyzed by internal staff and third parties, which includes various engineers and geologists, the
area and volume covered by mining rights, assumptions regarding extraction rates and duration of mining operations, and the
quality of in-place reserves and resources. The reserve and resource estimates as to both quantity and quality are updated from
time to time to reflect, among other matters, production of minerals from the Company's mining properties and new mining or
other data received.
23
There are numerous uncertainties inherent in estimating quantities and qualities of minerals and costs to mine recoverable
reserves and resources, including many factors beyond the Company's control. Estimates of mineral reserves and resources
necessarily depend upon a number of variable factors and assumptions, any one of which may, if incorrect, result in an estimate
that varies considerably from actual results. These factors and assumptions include:
•
Geologic and mining conditions, including the Company's ability to access certain mineral deposits as a result of the
nature of the geologic formations of coal deposits or other factors, which may not be fully identified by available
exploration data and may differ from past experience;
Demand for the Company's minerals;
Contractual arrangements, operating costs and capital expenditures;
Development and reclamation costs;
•
•
•
• Mining technology and processing improvements;
•
•
•
•
The effects of regulation by governmental agencies;
The ability to obtain, maintain and renew all required permits;
Employee health and safety; and
NACCO's ability to convert all or any part of mineral resources to economically extractable mineral reserves.
As a result, actual tonnage recovered from identified mining properties and estimated revenues, expenditures and cash flows
with respect to reserves and resources may vary materially from estimates. Thus, these estimates may not accurately reflect the
Company’s actual reserves and resources. Any material inaccuracy in estimates related to the Company's reserves or resources
could result in lower than expected revenues, higher than expected costs or decreased profitability and changes in future cash
flow, which could materially and adversely affect the Company business, results of operations, financial position and cash
flows. Additionally, reserve and resource estimates may be adversely affected in the future by interpretations of, or changes to,
the SEC’s property disclosure requirements for mining companies.
A defect in title or the loss of a leasehold interest in certain property could limit the Company's ability to mine coal
reserves or result in significant unanticipated costs.
The Company conducts a significant part of its coal mining operations on leased properties. A title defect or the loss of a lease
could adversely affect the ability to mine the associated coal reserves. The Company may not verify title to leased properties or
associated coal reserves until the Company has committed to developing those properties or coal reserves. The Company may
not commit to develop property or coal reserves until the Company has obtained necessary permits and completed exploration.
As such, the title to property that the Company intends to lease or mine may contain defects prohibiting the ability to conduct
mining operations. Similarly, leasehold interests may be subject to superior property rights of third parties. In order to conduct
mining operations on properties where these defects exist, the Company may incur unanticipated costs. In addition, some leases
require the Company to produce a minimum quantity of coal and/or pay minimum production royalties. The Company's
inability to satisfy those requirements may cause the leasehold interest to terminate.
Risks related to the NAMining segment
The Company has experienced growth in its NAMining business in recent periods and it may not be able to sustain
growth or manage future growth effectively.
The Company has expanded its overall NAMining business, operations and headcount in recent periods. NAMining’s operating
expenses may continue to increase as the Company scales the NAMining business, including growth outside of Florida, and
provides general and administrative resources to support NAMining’s growth. As NACCO continues to grow the NAMining
business, the Company must effectively integrate, develop and motivate new employees, as well as existing employees who are
promoted or moved into new roles, while maintaining the effectiveness of its business execution. In part, NAMining’s success
depends on its ability to integrate new customers in an efficient and effective manner. The Company anticipates that it will
continue to incur costs and capital expenditures associated with future growth prior to realizing the full measure of anticipated
long-term benefits, and the return on these investments may be lower, may develop more slowly than expected or may never be
realized. If the Company is unable to manage this growth and the associated expenses effectively, the Company may not be able
to take advantage of market opportunities or remain competitive. The Company may also fail to execute on its business plan or
respond to competitive pressures, any of which could adversely affect the NAMining business, operating results and financial
condition.
NAMining faces competition from aggregates producers that choose to self-perform mining operations and from other
mining companies.
24
NAMining faces competition from existing and prospective customers that are capable of performing, or engaging other
companies to perform the services NAMining provides. NAMining cannot be certain that its existing customers will continue to
outsource these services to NAMining in the future, which could adversely affect the NAMining business, operating results and
financial condition.
The Company is subject to risks involved in the development of new mining projects.
From time to time, the Company seeks to develop new mining projects, including the Thacker Pass project. The risks associated
with such projects can be substantial. New mining projects can take up to several years to complete, are complex and
require significant capital expenditures. These projects are subject to significant risks, including delays, extreme weather events,
unexpected increases in the cost of required materials, and disputes with third party providers of materials, equipment or
services, and a completed project may not yield the anticipated operational or financial benefit, any of which could have a
material adverse effect on the Company’s business, financial condition and results of operations.
NAMining operations are currently geographically concentrated and therefore subject to regional economic risk,
regulatory conditions, natural disasters, severe weather events or other circumstances affecting Florida.
As of December 31, 2021, over 80% of the quarries NAMining operates are located in Florida. A prolonged economic
downturn or adverse change in regulatory conditions in the Florida mining or construction industry could result in a significant
reduction in demand for NAMining’s services. The occurrence of one or more natural disasters, severe weather events, terrorist
attacks, or disruptive political events in Florida could adversely affect the NAMining business.
Risks related to the Minerals Management segment
The Company has no control over the timing of the development and operation of its natural gas, oil and coal reserves
extracted by third parties.
The Company owns mineral and royalty interests in the continental United States. The Company does not develop oil and gas
reserves and is not a natural gas and oil producer. The Company derives income from royalty-based leases under which lessees
make payments to the Company based on their sale of natural gas, oil and coal. As discussed in “Item 1. Business — Business
Developments" on page 2, the Company acquired additional mineral and royalty interests during 2021 and 2020 and plans to
continue to pursue acquisitions of additional mineral and royalty interests. Future royalty-based income is dependent on the
number of oil and gas wells being developed and operated on the Company’s mineral acreage. The decision to pursue
development and operation of oil and gas wells is made by third-party operators, not by the Company, and depends on a
number of factors outside of the Company's control, including fluctuations in commodity prices (primarily natural gas),
regulatory risk, the Company's lessees' willingness and ability to incur well-development and other operating costs, the rate of
production of the reserves and changes in the availability and continuing development of infrastructure. Lower commodity
prices may reduce the amount of oil and natural gas that third-party operators can produce economically. In the event that new
federal or state restrictions related to the hydraulic fracturing process are adopted in areas where the Company owns mineral
and royalty interests, the Company’s lessees may incur additional costs or permitting requirements to comply with such
requirements that may be significant and could result in added restrictions, delays or curtailments in the pursuit of exploration,
development, or production activities. In addition, if a lessee were to experience financial difficulty, the lessee might not be able
to pay its royalty payments or continue operations. A failure on the part of the lessee to make royalty payments gives the
Company the right to terminate the lease, repossess the property and enforce payment obligations under the lease. If the
Company repossessed any of its properties, it would seek a replacement lessee. However, the Company may not be able to find
a replacement lessee and, if it did, the Company might not be able to enter into a new lease on favorable terms within a
reasonable period of time. In addition, if the Company is able to enter into a new lease with a new lessee, the replacement lessee
may not achieve the same levels of production or sales prices as the lessee it replaced. Any of these risks could materially
reduce the Company’s expected royalty income and the Company’s profitability.
Minerals are a depleting asset. Unless the Company replaces existing mineral and royalty interests with new mineral
and royalty interests and third-party lessees develop those mineral and royalty interests, the Company’s reserves and
royalty income will decline.
Producing oil and natural gas reservoirs are generally characterized by declining production rates that vary depending upon
reservoir characteristics and other factors. Unless the Company’s third-party lessees conduct successful ongoing well
development activities or the Company continually acquires mineral and royalty interests, production and income related to the
Company’s mineral and royalty interests will decline as those reserves are depleted. The future cash flow and results of
operations of the Minerals Management segment are highly dependent on third-party operators’ success in developing the
25
Company’s current and future mineral and royalty interests. These operators may not have access to the capital needed to
develop the Company's mineral interests. The Company may not be able to acquire or find sufficient additional mineral and
royalty interests to replace third-party operators' current and future production. Further, the decline curve the Company uses to
project future royalty income is subject to numerous assumptions and limitations. Natural gas wells have high initial production
rates and follow a natural decline before settling into relatively stable, long-term production. Decline rates can vary due to
factors like well depth, well length, formation pressure, and facility design. Any of these risks could materially reduce the
Company’s expected royalty income and the Company’s profitability.
Substantially all of the Minerals Management segment’s revenues are derived from royalty payments that are based on
the price at which oil and natural gas produced from the acreage underlying the Company’s interests are sold. Prices of
oil and natural gas are volatile due to factors beyond the Company’s control. A substantial or extended decline in
commodity prices may adversely affect the Minerals Management segment’s financial condition or results of operations.
The Minerals Management segment’s revenues and operating results depend significantly upon the prevailing prices for oil and
natural gas. Historically, oil and natural gas prices have been volatile and are subject to fluctuations in response to changes in
supply and demand, market uncertainty and a variety of additional factors that are beyond the Company's control; market
expectations about future prices of oil and natural gas; the level of global oil and natural gas exploration and production; the
cost of exploring for, developing, producing and delivering oil and natural gas; the price and quantity of foreign imports and
U.S. exports of oil and natural gas; the level of U.S. domestic production; political and economic conditions in oil producing
regions; the ability of members of the Organization of Petroleum Exporting Countries to agree to and maintain oil price and
production controls; trading in oil and natural gas derivative contracts; the level of consumer product demand; weather
conditions and natural disasters; technological advances affecting energy consumption, energy storage and energy supply;
domestic and foreign governmental regulations and taxes; the continued threat of terrorism and the impact of military and other
action, including U.S. military operations in the Middle East and economic sanctions such as those imposed by the U.S. on oil
and gas exports from Iran; the proximity, cost, availability and capacity of oil and natural gas pipelines and other transportation
facilities; the price and availability of alternative fuels; and overall domestic and global economic conditions. A substantial or
extended decline in commodity prices may adversely affect the Minerals Management segment’s financial condition or results
of operations.
Risks related to corporate structure
The Company’s stock repurchase program could affect the price of NACCO’s common stock and increase volatility and
may not enhance long-term shareholder value.
The Company’s Board of Directors has authorized a stock repurchase program. The timing and amount of any repurchases
under the stock repurchase program are determined at the discretion of the Company's management based on a number of
factors, including the availability of capital, other capital allocation alternatives, market conditions for the Company's Class A
common stock and other legal and contractual restrictions. The stock repurchase program does not require the Company to
acquire any specific number of shares and may be modified, suspended, extended or terminated without prior notice and may be
executed through open market purchases, privately negotiated transactions or otherwise.
Repurchases under the stock repurchase program could affect the price of the Company's Class A common stock. The existence
of a stock repurchase program could cause the price of the Company's Class A common stock to be higher than it would be in
the absence of such a program and could potentially reduce the market liquidity for the Company’s Class A common stock.
There can be no assurance that any stock repurchases will enhance shareholder value because the market price of the
Company’s Class A common stock may decline below the levels at which the Company repurchased the shares. Although the
stock repurchase program is intended to enhance long-term shareholder value, there is no assurance that it will do so and short-
term price fluctuations in the Class A common stock could reduce the program’s effectiveness. Furthermore, the stock
repurchase program does not obligate the Company to repurchase any dollar amount or number of shares of the Company's
Class A common stock, and it may be suspended or discontinued at any time and any suspension or discontinuation could cause
the market price of the Company's Class A common stock to decline.
The price of NACCO's securities may be volatile.
The price of the Company's common stock may fluctuate due to a variety of market and industry factors that may materially
reduce the market price of NACCO's common stock regardless of operating performance, including, among others: (i) actual or
anticipated fluctuations in the Company's quarterly and annual results and those of other public companies in the industry; (ii)
industry cycles and trends; (iii) changes in government regulation; (iv) potential or actual military conflicts or acts of terrorism;
26
(v) announcements concerning NACCO, its customers or its competitors; (vi) lack of trading liquidity as a result of low trading
volumes could make it difficult for investors to sell shares; and (vii) the general state of the securities market. In addition, the
stock market in general has experienced significant volatility that often has been unrelated to the operating performance of
companies whose shares are traded. These market fluctuations could adversely affect the trading price of the Company's
common stock, regardless of NACCO's actual operating performance. As a result of all of these factors, investors in the
Company's common stock may not be able to resell their stock at or above the price they paid or at all. Further, NACCO could
be the subject of securities class action litigation due to any such stock price volatility, which could divert management’s
attention and have a material adverse effect on the Company's operating results.
The amount and frequency of dividend payments made on NACCO's common stock could change.
The Board of Directors has the power to determine the amount and frequency of the payment of dividends. Decisions regarding
whether or not to pay dividends and the amount of any dividends are based on earnings, capital and future expense
requirements, financial conditions and other factors the Board of Directors may consider. Accordingly, holders of NACCO's
common stock should not rely on past payments of dividends in a particular amount as an indication of the amount of dividends
that will be paid in the future.
NACCO's certificate of incorporation and by-laws include provisions that may discourage a takeover attempt.
Provisions contained in the Company's certificate of incorporation and by-laws and Delaware law could make it more difficult
for a third-party to acquire the Company, even if doing so might be beneficial to NACCO's stockholders. Provisions of the
Company's by-laws and certificate of incorporation impose various procedural and other requirements that could make it more
difficult for stockholders to affect certain corporate actions. These provisions could limit the price that certain investors might
be willing to pay in the future for shares of NACCO's common stock and may have the effect of delaying or preventing a
change in control.
NACCO is a smaller reporting company and cannot be certain if the reduced disclosure requirements applicable to
smaller reporting companies will make the Company's common stock less attractive to investors.
The Company is currently a “smaller reporting company” as defined in the Securities Exchange Act of 1934, and thus allowed
to provide simplified executive compensation disclosures and other decreased disclosure in SEC filings. The reduced
disclosures may make it more difficult to compare the Company's performance with other public companies.
NACCO cannot predict whether investors will find the Company's common stock less attractive because of these exemptions. If
some investors find NACCO's common stock less attractive as a result, there may be a less active trading market for the
Company's common stock and the stock price may be more volatile.
Certain members of the Company's extended founding family own a substantial amount of its Class A and Class B
common stock and, if they were to act in concert, could control the outcome of director elections and other stockholder
votes on significant corporate actions.
The Company has two classes of common stock: Class A common stock and Class B common stock. Holders of Class A
common stock are entitled to cast one vote per share and, as of December 31, 2021, accounted for approximately 26 percent of
the voting power of the Company. Holders of Class B common stock are entitled to cast ten votes per share and, as of
December 31, 2021, accounted for the remaining voting power of the Company. As of December 31, 2021, certain members of
the Company's extended founding family held approximately 34 percent of the Company's outstanding Class A common stock
and approximately 98 percent of the Company's outstanding Class B common stock. On the basis of this common stock
ownership, certain members of the Company's extended founding family could have exercised approximately 81 percent of the
Company's total voting power. Although there is no voting agreement among such extended family members, in writing or
otherwise, if they were to act in concert, they could control the outcome of director elections and other stockholder votes on
significant corporate actions, such as certain amendments to the Company's certificate of incorporation and sales of the
Company or substantially all of its assets. Because certain members of the Company's extended founding family could prevent
other stockholders from exercising significant influence over significant corporate actions, the Company may be a less
attractive takeover target, which could adversely affect the market price of its common stock.
The Company’s effective income tax rate could be volatile and materially change as a result of changes in tax laws, mix
of earnings and other factors.
General Risk Factors
27
The Company is subject to income taxes in the United States and the effective income tax rate is impacted by certain U.S.
federal income tax benefits currently available to coal mining and oil and gas exploration and development companies. Future
results of operations could be affected by changes in the Company’s effective income tax rate as a result of an increase in the
statutory tax rate or the reduction or elimination of percentage depletion as well as changes in the mix of earnings between
entities that benefit from percentage depletion and those that do not.
Current and future capital and credit market conditions could adversely affect the Company’s ability to obtain bank
financing on reasonable terms. Certain financial institutions have acted to limit available financing for companies in the
fossil fuel industry, including coal mining, which could result in increases in costs of borrowing or in the Company’s
ability to maintain financing at current levels.
The Company may be unable to obtain financing on reasonable terms. Historically, the Company has addressed its liquidity
needs (including funds required to pay dividends and fund working capital and planned capital expenditures) with operating
cash flow and borrowings under credit facilities. The Company’s wholly-owned subsidiary, NACoal, has a revolving line of
credit of up to $150.0 million that expires in November 2025 (the "NACoal Facility"). The Company’s ability to access the
capital markets and the costs and terms of available financing depends on many factors, including perceived credit risks of
companies with coal and/or oil and gas exposure as a result of current market sentiment for fossil fuels. Certain financial
institutions have taken actions to limit available financing to entities that produce or use fossil fuels. The volatility in the energy
industry combined with recent bankruptcies and additional perceived credit risks of companies with coal and/or oil and gas
exposure has resulted in traditional bank lenders seeking to reduce or eliminate their lending exposure to these companies. An
inability to obtain bank financing, or obtaining a refinancing with terms that are not as favorable as the existing terms of such
indebtedness, could have a material adverse effect on the Company's operating results and financial condition.
Failure to obtain financial assurance to secure reclamation and other long-term obligations, including surety bonds and
letters of credit on acceptable terms, could affect NACCO's ability to mine.
Federal and state laws require the Company to provide financial assurance or financial security to secure performance or
payment of certain long-term obligations, such as mine closure or reclamation costs, federal and state workers’ compensation
and black lung benefits costs, leases and other obligations. Future federal and state laws and regulations may require higher
amounts of financial security, including as a result of changes to certain factors used to calculate the bonding or security
amounts. Bond issuers may demand higher fees or additional collateral, including cash or letters of credit or other terms less
favorable upon renewals. As the Company is required by state and federal law to have bonds or other acceptable security in
place before mining can commence or continue, the failure to maintain surety bonds, letters of credit or other guarantees or
security arrangements would materially and adversely affect NACCO's ability to mine. That failure could result from a variety
of factors, including lack of availability, higher expense or unfavorable market terms, the exercise by third-party surety bond
issuers of their right to refuse to renew the surety and restrictions on availability of collateral for current and future third-party
surety bond issuers under the terms of the Company's financing arrangements. In addition, as a result of increasing credit
pressures on the coal industry, it is possible that surety bond providers could demand cash collateral as a condition to providing
or maintaining surety bonds. Any such demands, could have a material adverse impact on the Company’s liquidity and financial
position. If the Company is unable to meet collateral requirements and cannot otherwise obtain or retain required surety bonds,
it may be unable to satisfy legal requirements necessary to conduct mining operations. Difficulty in acquiring surety bonds, or
additional collateral requirements, would increase the Company’s costs and likely require greater use of alternative sources of
funding for this purpose, which would reduce the Company’s liquidity.
Insurance coverage is increasingly expensive, contains more stringent terms and may be difficult to obtain in the future.
A number of global insurance companies have taken steps to limit coverage for companies in the fossil fuel industry,
including coal mining, which could result in significant increases in costs of insurance or in the Company’s ability to
maintain insurance coverage at current levels.
The Company holds a number of insurance policies, including director and officers’ liability and property and casualty
insurance coverages. Because the Company is involved in coal mining, costs of insurance may increase substantially or
insurance carriers may limit or decide not to insure the Company in the future. In addition, if the Company makes significant
insurance claims under the Company’s insurance policies, such claims may have a material adverse effect on its ability to
obtain future insurance coverage at commercially reasonable rates. Limited, or an inability to obtain, insurance coverage,
significant increases in the premiums or deductibles of insurance, or losses in excess of its liability insurance coverage limits,
could have a material adverse effect on the Company's operating results and financial condition.
28
Increasing emphasis and changing expectations with respect to environmental, social and governance matters may
impose additional costs on the Company or expose the Company to new or additional risks.
Expectations relating to environmental, social and governance (“ESG”) matters have been rapidly evolving and increasing.
Government organizations are enhancing or advancing legal and regulatory requirements specific to ESG matters. The
heightened focus on ESG issues requires the continuous monitoring of various and evolving laws, regulations, standards and
expectations and the associated reporting requirements. Investor advocacy groups, certain institutional investors, investment
funds and other influential investors are also increasingly focused on ESG practices. The Company could face pressures from
investors, who are increasingly focused on climate change, to prioritize sustainable energy practices, reduce the Company’s
carbon footprint and promote sustainability. Investors may request the Company implement ESG procedures or standards as a
condition to maintain their investment or to make further investments. Lenders and insurers may also limit lending to and
insuring of companies that do not meet certain ESG measures endorsed by them. Additionally, the Company may face
reputational challenges in the event its ESG practices are inconsistent with the third party views of acceptable ESG practices.
Companies which do not adapt to or comply with regulatory, investor or stakeholder expectations and standards, which are
evolving, or which are perceived to have not responded appropriately, may suffer from reputational damage and the business,
financial condition, and/or stock price of such a company could be materially and adversely affected.
The Company may be subject to litigation seeking to hold energy companies accountable for the effects of climate
change.
Increasing attention to climate change risk has also resulted in a recent trend of governmental investigations and private
litigation by local and state governmental agencies as well as private plaintiffs in an effort to hold energy companies
accountable for the effects of climate change. Other public nuisance lawsuits have been brought in the past against power, coal,
oil and gas companies alleging that their operations are contributing to climate change. The plaintiffs in these suits sought
various remedies, including punitive and compensatory damages and injunctive relief. While the U.S. Supreme Court held that
any federal common law had been displaced by the CAA and thus dismissed the public nuisance claims against the defendants
in those cases, tort-type liabilities remain a possibility and a source of concern. We could incur substantial legal costs associated
with defending such lawsuits in the future. Government entities in certain states have brought similar claims seeking to hold a
wide variety of companies that produce fossil fuels liable for the alleged impacts of the GHG emissions attributable to those
fuels or for other grounds related to climate change, such as improper disclosure of climate change risks. Those lawsuits allege
damages as a result of climate change and the plaintiffs are seeking unspecified damages and abatement under various tort
theories. We have not been made a party to these suits, but it is possible that we could be included in similar future lawsuits
initiated by state and local governments as well as private claimants.
The Company’s business could suffer if NACCO’s information technology systems are disrupted, cease to operate
effectively or if the Company experiences a security breach, a cyber incident or cyber attack.
Like many other companies, the Company is the target of malicious cyber attack attempts in the normal course of business.
Cybersecurity incidents involving businesses and other institutions are on the rise. Cyber threats are rapidly evolving and those
threats and the means for obtaining access to information in digital and other storage media are becoming increasingly
sophisticated. Cyber threats and cyber attackers can be sponsored by nation states or sophisticated criminal organizations or be
the work of independent hackers.
As cyber threats evolve and become more difficult to detect and successfully defend against, one or more cyber attacks might
defeat the Company's or a third-party service provider's security measures in the future. Employee error or other irregularities
may also result in a failure of security measures and a breach of information systems. Moreover, hardware, software or
applications the Company may use have inherent defects of design, manufacture or operations or could be inadvertently or
intentionally implemented or used in a manner that could compromise information security.
A security breach and loss of information may not be discovered for a significant period of time after it occurs. Any
compromise of data security could result in a violation of applicable privacy and other laws or standards, the loss of valuable
business data, or a disruption of the Company's business. A security breach involving the misappropriation, loss or other
unauthorized disclosure of sensitive or confidential information could give rise to unwanted media attention, materially damage
customer relationships and the Company's reputation, and result in fines, fees, or liabilities, which may not be covered by
insurance policies.
The Company relies on information technology systems to operate its business and to record and process transactions; respond
to customer inquiries; purchase supplies; provide services; deliver inventory on a timely basis; and maintain cost-efficient
29
operations. Despite the Company's efforts, the Company’s information technology systems may be vulnerable, from time to
time, to damage or interruption from user error, computer viruses, power outages, third-party intrusions and other technical
malfunctions.
Through the Company’s business operations, the Company collects and stores confidential information from its customers and
vendors and personal information and other confidential information from its employees. Although the Company has taken
steps designed to safeguard such information, there can be no assurance that such information will be protected against
unauthorized access, use or disclosure. Unauthorized parties may penetrate the Company’s or its vendors’ network security and,
if successful, misappropriate such information. Additionally, methods to obtain unauthorized access to confidential information
change frequently and may be difficult to detect, which can impact the Company’s ability to respond appropriately.
The Company could be subject to liability for failure to comply with privacy and information security laws, for failing to
protect personal information or for failing to respond appropriately. Loss, unauthorized access to, or misuse of confidential or
personal information could disrupt the Company’s operations, damage the Company’s reputation, and expose the Company to
claims from customers, financial institutions, regulators, employees and other persons, any of which could have an adverse
effect on the Company’s business, financial condition and results of operations.
Security breaches, cyber incidents or cyber attacks could include, among other things, computer viruses, malicious or
destructive code, ransomware, social engineering attacks (including phishing and impersonation), hacking, denial of service
attacks and other attacks. Cybersecurity threats to, and incidents involving, vendors and other third-parties who support the
Company's activities could impact us. For example, although the Company has not experienced any material impacts from the
SolarWinds Orion cybersecurity breach that was widely publicized in December 2020, similar future events could have a
material impact on the Company. The Company is continuously installing new and upgrading existing information technology
systems. The Company uses employee awareness training around phishing, malware, and other cyber risks. The Company
believes these incidents are likely to continue and is unable to predict the direct or indirect impact of future attacks or breaches
to business operations.
The Company’s results of operations, financial condition, cash flows and stock price could be adversely affected by
pandemics, epidemics or other public health emergencies, such as the global outbreak of COVID-19.
The Company’s results of operations, financial condition, cash flows and stock price could be adversely affected by pandemics,
epidemics or other public health emergencies, such as the global outbreak of COVID-19. The COVID-19 pandemic resulted in
governments around the world implementing stringent measures to help control the spread of the virus. Although the Company
has continued to operate facilities consistent with federal guidelines and state and local orders, the ongoing COVID-19
pandemic and the preventive or protective actions taken by governmental authorities may have a material adverse effect on the
Company’s operations, work force, supply chain or customers, including business shutdowns or disruptions. The extent to
which COVID-19 may adversely impact the Company's businesses depends on future developments, which are highly uncertain
and unpredictable, including the extent of new outbreaks, the extent to which additional actions to mitigate the COVID-19
pandemic may be needed, the nature of government public health guidelines and the public's adherence to those guidelines. Any
resulting financial impact cannot reasonably be estimated at this time, but could have a material adverse effect on the
Company’s financial condition, cash flows and results of operations.
Even after the COVID-19 pandemic has subsided, the Company may experience material adverse effects due to a decline in
economic activity.
The Company’s operations could be disrupted by natural or human causes beyond its control.
The Company’s operations are subject to disruption from natural or human causes beyond its control, including physical risks
from hurricanes, severe storms, floods and other forms of severe weather, accidents, fires, earthquakes, terrorist acts and
epidemic or pandemic diseases such as the coronavirus, any of which could result in suspension of operations or harm to people
or the environment. While all of the Company’s operations are located in the United States, the Company participates in a
global supply chain, and if a disease spreads sufficiently to cause a pandemic (or to cause the fear of a pandemic to rise) or
governments regulate or restrict the flow of labor or products or impede the travel of Company personnel, the Company’s
ability to conduct normal business operations could be impacted which could adversely affect the Company’s results of
operations and liquidity.
30
Item 1B. UNRESOLVED STAFF COMMENTS
None.
Item 2. PROPERTIES
Coal Mining Segment - Operations
1.0
INTRODUCTION
NACCO-owned Resources and Reserves
Information concerning the Company’s mining properties in this Form 10-K have been prepared in accordance with the
requirements of subpart 1300 of Regulation S-K, which first became applicable to the Company for the year ended December
31, 2021. These requirements differ significantly from the previously applicable disclosure requirements of SEC Industry Guide
7. Among other differences, subpart 1300 of Regulation S-K requires the Company to disclose its mineral resources, in addition
to its mineral reserves, both in the aggregate and for each of the Company’s individually material mining properties.
As used in this Report on Form 10-K, the terms “mineral resource,” “measured mineral resource,” “indicated mineral resource,”
“inferred mineral resource,” “mineral reserve,” “proven mineral reserve” and “probable mineral reserve” are defined and used
in accordance with subpart 1300 of Regulation S-K. Under subpart 1300 of Regulation S-K, mineral resources may not be
classified as “mineral reserves” unless the determination has been made by a qualified person that the mineral resources can be
the basis of an economically viable project. Readers are specifically cautioned not to assume that any part or all of the mineral
deposits (including any mineral resources) in these categories will ever be converted into mineral reserves, as defined by the
SEC.
Readers are cautioned that, except for that portion of mineral resources classified as mineral reserves, mineral resources do not
have demonstrated economic value. Inferred mineral resources are estimates based on limited geological evidence and sampling
and have a too high of a degree of uncertainty as to their existence to apply relevant technical and economic factors likely to
influence the prospects of economic extraction in a manner useful for evaluation of economic viability. Estimates of inferred
mineral resources may not be converted to a mineral reserve. It cannot be assumed that all or any part of an inferred mineral
resource will ever be upgraded to a higher category. A significant amount of exploration must be completed in order to
determine whether an inferred mineral resource may be upgraded to a higher category. Therefore, readers are cautioned not to
assume that all or any part of an inferred mineral resource exists, that it can be the basis of an economically viable project, or
that it will ever be upgraded to a higher category. Likewise, readers are cautioned not to assume that all or any part of measured
or indicated mineral resources will ever be converted to mineral reserves. See "Item 1A - “Risk Factors” on page 20.
The information that follows is derived, for the most part, from, and in some instances is an extract from, the technical report
summaries (“TRS’s”) prepared in compliance with the Item 601(b)(96) and subpart 1300 of Regulation S-K. Portions of the
following information are based on assumptions, qualifications and procedures that are not fully described herein. Reference
should be made to the full text of the TRS’s, incorporated herein by reference and made a part of this Report on Form 10-K.
TCoteau, Coyote Creek, Falkirk and MLMC, collectively referred to as “Mines subject to SEC Section 1300 reporting”, each
wholly-owned subsidiaries of NACCO, operate surface coal mines under long-term contracts with power generation companies
pursuant to a service-based business model. At each of these mines, the Company owns or controls the mineral resources and
reserves.
The Company operates additional surface coal mines where the customer owns or controls the reserves. The Company conducts
activities to extract these customer-owned reserves pursuant to long-term contracts.
Locations of the properties subject to SEC Section 1300 reporting are shown in Figure 1.1 Surface Coal Mines Operational
During 2021 Subject to SEC Section 1300 reporting.
31
Figure 1.1 Surface Coal Mines Operational During 2021 Subject to SEC Section 1300 Reporting
At all Mines subject to SEC Section 1300 Reporting other than MLMC, the Company is paid a management fee per ton of coal
or heating unit (MMBtu) delivered. Each contract specifies the indices and mechanics by which fees change over time,
generally in line with broad measures of U.S. inflation. The customers are responsible for funding all mine operating cost,
including final mine reclamation, and directly or indirectly providing all of the capital required to build and operate the mine.
This contract structure eliminates the Company's exposure to spot coal market price fluctuations.
The MLMC contract is the only operating coal contract in which the Company is responsible for all operating costs, capital
requirements and final mine reclamation; therefore, MLMC is consolidated within NACCO’s financial statements. MLMC sells
coal to its customer at a contractually agreed-upon price which adjusts monthly, primarily based on changes in the level of
established indices which reflect general U.S. inflation rates. Profitability at MLMC is affected by customer demand for coal
and changes in the indices that determine sales price and actual costs incurred.
A summary of coal production at the Mines subject to SEC Section 1300 Reporting for the past three years has been tabulated
and is presented on Table 1.1 Production Summary.
The Coteau Properties Company
The Falkirk Mining Company
Coyote Creek Mining Company
Mississippi Lignite Mining Company
Totals
Tons (in millions)
2019
13.5
7.4
1.7
2.6
25.2
2020
12.6
7.2
2
2.5
24.3
2021
12.5
7.9
2
3
25.4
Table 1.1 Production Summary
32
2.0 MATERIAL MINING PROPERTIES
2.1 Freedom Mine — The Coteau Properties Company
The Freedom Mine generally produces between 12.5 million and 13.5 million tons of lignite coal annually. The mine started
delivering coal in 1983. All production from the mine is delivered to Dakota Coal Company, a wholly owned subsidiary of
Basin Electric. Dakota Coal Company then sells the coal to the Synfuels Plant, Antelope Valley Station and Leland Olds
Station, all of which are operated by affiliates of Basin Electric. The Synfuels Plant is a coal gasification plant that
manufactures synthetic natural gas and produces fertilizers, solvents, phenol, carbon dioxide, and other chemical products for
sale.
During 2020, Basin Electric informed Coteau that it is considering changes that may result in modifications to its Synfuels Plant
that could potentially reduce or eliminate coal requirements at the Synfuels Plant. Basin Electric indicated that if it decides to
proceed with any changes that could reduce or eliminate the use of coal, the feedstock change is not expected to occur before
2026.
During August 2021, Bakken and Basin Electric signed a non-binding term sheet to purchase the assets of the Synfuels Plant.
Bakken stated the closing date is expected to be April 1, 2023. As part of the term sheet between Basin Electric and Bakken,
Basin Electric indicated that the Synfuels Plant will continue existing operations through 2025. The closing is subject to the
satisfaction of specified conditions. Basin Electric is also considering other options for the Synfuels Plant if the transaction with
Bakken does not close.
The Freedom Mine, operated by Coteau, is located approximately 90 miles northwest of Bismarck, North Dakota. The main
entrance to the Freedom Mine is accessed by means of a paved road and is located on County Road 15. Coteau holds 380 leases
granting the right to mine approximately 34,016 acres of coal interests and the right to utilize approximately 23,455 acres of
surface interests. In addition, Coteau owns in fee 33,805 acres of surface interests and 4,107 acres of coal interests.
Substantially all of the leases held by Coteau were acquired in the early 1970s and have been replaced with new leases or have
lease terms for a period sufficient to meet Coteau’s contractual production requirements.
The reserves are located in Mercer County, North Dakota, starting approximately two miles north of Beulah, North Dakota. The
center of the basin is located near the city of Williston, North Dakota, approximately 100 miles northwest of the Freedom Mine.
The economically mineable coal in the reserve occurs in the Sentinel Butte Formation, and is overlain by the Coleharbor
Formation. The Coleharbor Formation unconformably overlies the Sentinel Butte Formation. It includes all of the
unconsolidated sediments resulting from deposition during glacial and interglacial periods. Lithologic types include gravel,
sand, silt, clay and till. The modified glacial channels are in-filled with gravels, sands, silts and clays overlain by till. The
coarser gravel and sand beds are generally limited to near the bottom of the channel fill. The general stratigraphic sequence in
the upland portions of the reserve area consists of till, silty sands and clayey silts.
Coteau currently has all permits in place for the Freedom Mine to operate through 2031. Permit expansions required to extend
the life of the mine through 2045 will be acquired as needed. No mineral processing occurs at the Freedom Mine.
2.2 Falkirk Mine — The Falkirk Mining Company
The Falkirk Mine generally produces between 7 million and 8 million tons of lignite coal annually. The mine started delivering
coal in 1978 primarily for the Coal Creek Station, an electric power generating station owned by GRE. In 2014, Falkirk began
delivering coal to Spiritwood Station, another electric power generating station owned by GRE.
In May 2020, GRE announced its intent to sell or retire Coal Creek Station and modify Spiritwood Station to be fueled by
natural gas. During June 2021, GRE entered into an agreement to sell Coal Creek Station and the adjacent high-voltage direct
current transmission line to Bismarck, North Dakota-based Rainbow Energy and its affiliates. The closing of this sale is subject
to the satisfaction of certain conditions and presently, the transaction is expected to close in the second quarter of 2022.
The Falkirk Mine, operated by Falkirk, is located approximately 50 miles north of Bismarck, North Dakota on a paved access
road off U.S. Highway 83. Falkirk holds 335 leases granting the right to mine approximately 43,486 acres of coal interests and
the right to utilize approximately 24,324 acres of surface interests. In addition, Falkirk owns in fee 40,666 acres of surface
interests and 1,788 acres of coal interests. Substantially all of the leases held by Falkirk were acquired in the early 1970s with
initial terms that have been further extended by the continuation of mining operations.
33
The reserves are located in McLean County, North Dakota, from approximately nine miles northwest of the town of Washburn,
North Dakota to four miles north of the town of Underwood, North Dakota. Structurally, the area is located on an intercratonic
basin containing a thick sequence of sedimentary rocks. The economically mineable coals in the reserve occur in the Sentinel
Butte Formation and the Bullion Creek Formation and are unconformably overlain by the Coleharbor Formation. The Sentinel
Butte Formation conformably overlies the Bullion Creek Formation. The general stratigraphic sequence in the upland portions
of the reserve area (Sentinel Butte Formation) consists of till, silty sands and clayey silts, main hagel lignite bed, silty clay,
lower lignite of the hagel lignite interval and silty clays. Beneath the Tavis Creek, there is a repeating sequence of silty to sand
clays with generally thin lignite beds.
There are no outstanding permits related to the life of mine ("LOM") plan awaiting regulatory approval. The Falkirk Mining
Company currently has all permits in place to operate and adhere to the current mine plan. No mineral processing occurs at the
Falkirk Mine.
2.3 Coyote Creek Mine - Coyote Creek Mining Company, LLC
The Coyote Creek Mine generally produces between 1.5 million and 2.0 million tons of lignite annually. The mine began
delivering coal in 2016 to the Coyote Station owned by Otter Tail Power Company, Northern Municipal Power Agency,
Montana-Dakota Utilities Company and Northwestern Corporation. In September 2021, Otter Tail Power Company filed its
2022 Integrated Resource Plan in Minnesota and North Dakota which included its intent to start the process of withdrawal from
its 35 percent ownership interest in Coyote Station power plant with an anticipated exit from the plant by December 31, 2028.
The Coyote Creek Mine is located approximately 70 miles northwest of Bismarck, North Dakota. The main entrance to the
Coyote Creek Mine is accessed by means of a four-mile paved road extending west off of State Highway 49. Coyote Creek
holds a sublease to 86 leases granting the right to mine approximately 8,129 acres of coal interests and the right to utilize
approximately 15,168 acres of surface interests. In addition, Coyote Creek Mine owns in fee 160 acres of surface interests and
has four easements to conduct coal mining operations on approximately 352 acres.
The reserves are located in Mercer County, North Dakota, starting approximately six miles southwest of Beulah, North Dakota.
The center of the basin is located near the city of Williston, North Dakota, approximately 110 miles northwest of the Coyote
Creek Mine. The economically mineable coal in the reserve occurs in the Sentinel Butte Formation, and is overlain by the
Coleharbor Formation. The Coleharbor Formation unconformably overlies the Sentinel Butte Formation. It includes all of the
unconsolidated sediments resulting from deposition during glacial and interglacial periods. Lithologic types include gravel,
sand silt, clay and till. The modified glacial channels are in-filled with gravels, sands, silts and clays overlain by till. The
coarser gravel and sand beds are generally limited to near the bottom of the channel fill. The general stratigraphic sequence in
the upland portions of the reserve area consists of till, silty sands and clayey silts.
There are no outstanding permits related to the LOM plan awaiting regulatory approval. Coyote currently has all permits in
place for the Coyote Creek Mine to operate and adhere to a mine plan projected through 2040. No mineral processing occurs at
the Coyote Creek Mine.
2.4 Red Hills Mine — Mississippi Lignite Mining Company
The Red Hills Mine generally produces between 2 million and 3 million tons of lignite coal annually. The Red Hills Mine
started delivering coal in 2000. All production from the mine is delivered to its customer's Red Hills Power Plant.
The Red Hills Mine, operated by MLMC, is located approximately 120 miles northeast of Jackson, Mississippi. The entrance to
the mine is by means of a paved road located approximately one mile west of Highway 9. MLMC owns in fee approximately
7,343 acres of surface interest and 4,425 acres of coal interests. MLMC holds leases granting the right to mine approximately
5,794 acres of coal interests and the right to utilize approximately 5,597 acres of surface interests. MLMC holds subleases
under which it has the right to mine approximately 1,593 acres of coal interest. The majority of the leases held by MLMC were
originally acquired during the mid-1970s to the early 1980s with terms extending 50 years, many of which can be further
extended by the continuation of mining operations.The lignite deposits of the Gulf Coast are found primarily in a narrow band
of strata that outcrops/subcrops along the margin of the Mississippi Embayment. The potentially exploitable tertiary lignites in
Mississippi are found in the Wilcox Group. The outcropping Wilcox is composed predominately of non-marine sediments
deposited on a broad flat plain.
MLMC currently has all permits in place for the Red Hills Mine to operate and adhere to a mine plan projected through April
2032. No mineral processing occurs at the Red Hills Mine.
34
3.0 MINERAL RESOURCES AND RESERVES
Mineral resources and reserves have been summarized from the TRS for each mine subject to SEC Section 1300 reporting and
have been included as Table 3.1 and Table 3.2. Qualities are being reported on an as-received moisture basis except for sodium
which is from the mineral analysis of ash.
SUMMARY MINERAL RESOURCES AS OF DECEMBER 31, 2021 BASED ON CUT-OFF GRADES OF
Coteau - $1.70/mmBTU, Falkirk - $2.60/mmBTU, Coyote - $2.27/mmBTU, and MLMC - $30.00/ton
Tonnage
Measured mineral resources
Grades/qualities
Lignite Coal:
Calorific
Value (Btu/lb)
Moisture
(%wt)
Ash (%wt)
Sulfur
(%wt)
Sodium
(%wt)
The Coteau Properties Company
The Falkirk Mining Company
Coyote Creek Mining Company
Mississippi Lignite Mining Company
Total
322,310,200
78,420,784
31,202,000
11,475,500
443,408,484
6,779
6,534
6,943
5,110
6,704
37.64
39.83
36.63
44.0
38.12
7.27
6.65
7.25
14.1
7.34
0.89
0.57
0.94
0.60
0.83
5.62
NA
7.78
NA
5.81
Tonnage
Indicated mineral resources
Grades/qualities
Lignite Coal:
Calorific
Value (Btu/lb)
Moisture
(%wt)
Ash (%wt)
Sulfur
(%wt)
Sodium
(%wt)
The Coteau Properties Company
The Falkirk Mining Company
Coyote Creek Mining Company
Mississippi Lignite Mining Company
Total
8,188,400
199,721
3,905,900
16,169,100
28,463,121
6,776
6,317
6,942
5,270
5,940
37.92
37.10
36.55
44.3
41.35
7.22
10.69
7.39
14.3
11.29
0.90
0.73
0.97
0.7
0.79
6.36
NA
7.70
NA
6.80
Lignite Coal:
Tonnage
Grades/qualities
Measured + indicated mineral resources
Calorific
Value (Btu/lb)
Moisture
(%wt)
Ash (%wt)
Sulfur
(%wt)
Sodium
(%wt)
The Coteau Properties Company
The Falkirk Mining Company
Coyote Creek Mining Company
Mississippi Lignite Mining Company
Total
330,498,600
78,620,505
35,107,900
27,644,600
471,871,605
6,778
6,534
6,943
5,200
6,657
37.64
39.82
36.62
44.2
38.31
7.27
6.66
7.26
14.2
7.57
0.89
0.57
0.94
0.7
0.83
5.63
NA
7.77
NA
5.84
Lignite Coal:
Calorific
Value (Btu/lb)
Moisture
(%wt)
Ash (%wt)
Sulfur
(%wt)
Sodium
(%wt)
Tonnage
Inferred mineral resources
Grades/qualities
The Coteau Properties Company
The Falkirk Mining Company
Coyote Creek Mining Company
Mississippi Lignite Mining Company
Total
15,000
0
0
0
15,000
6,463
NA
NA
NA
6,463
37.84
NA
NA
NA
37.84
9.78
NA
NA
NA
9.78
1.02
NA
NA
NA
1.02
1.59
NA
NA
NA
1.59
Table 3.1 Mineral Resources Summary
35
SUMMARY MINERAL RESERVES AS OF DECEMBER 31, 2021 BASED ON CUT-OFF GRADES OF
Coteau - $1.55/mmBTU, Falkirk - $2.60/mmBTU, Coyote - $2.27/mmBTU, and MLMC - $28.04/ton
Tonnage
Proven mineral reserves
Grades/qualities
Lignite Coal:
Calorific
Value (Btu/lb)
Moisture
(%wt)
Ash (%wt)
Sulfur
(%wt)
Sodium
(%wt)
The Coteau Properties Company
The Falkirk Mining Company
Coyote Creek Mining Company
Mississippi Lignite Mining Company
Total
253,946,500
78,420,784
31,202,000
17,167,900
380,737,184
6,779
6,534
6,943
5,070
6,665
37.70
39.83
36.63
43.5
38.31
7.19
6.65
7.25
15.0
7.44
0.89
0.57
0.94
0.6
0.82
5.12
NA
7.78
NA
5.41
Tonnage
Probable mineral reserves
Grades/qualities
Lignite Coal:
Calorific
Value (Btu/lb)
Moisture
(%wt)
Ash (%wt)
Sulfur
(%wt)
Sodium
(%wt)
The Coteau Properties Company
The Falkirk Mining Company
Coyote Creek Mining Company
Mississippi Lignite Mining Company
Total
3,552,300
199,721
3,905,900
9,447,600
17,105,521
6,756
6,317
6,942
5,080
5,868
38.29
37.10
36.55
43.1
40.54
6.78
10.69
7.39
15.0
11.50
0.84
0.73
0.97
0.6
0.74
5.40
NA
7.70
NA
6.60
Tonnage
Total mineral reserves
Grades/qualities
Lignite Coal:
Calorific
Value (Btu/lb)
Moisture
(%wt)
Ash (%wt)
Sulfur
(%wt)
Sodium
(%wt)
The Coteau Properties Company
The Falkirk Mining Company
Coyote Creek Mining Company
Mississippi Lignite Mining Company
Total
257,498,800
78,620,505
35,107,900
26,615,500
397,842,705
6,779
6,534
6,943
5,070
6,631
37.71
39.82
36.62
43.4
38.41
7.19
6.66
7.26
15.0
7.61
0.88
0.57
0.94
0.6
0.81
5.12
NA
7.77
NA
5.44
Table 3.2 Mineral Reserves Summary
Internal Control Disclosure Over Mineral Resources and Reserves
The modeling and analysis of the Company’s resources and reserves has been developed by Company mine personnel and
reviewed by several levels of internal management, including the QP, and in some instances, third parties. The development of
such resources and reserves estimates, including related assumptions, was a collaborative effort between the QP, Company staff
and in some instances, third parties. This section summarizes the internal control considerations for the Company’s
development of estimations, including assumptions, used in resource and reserve analysis and modeling.
When determining resources and reserves, as well as the differences between resources and reserves, management developed
specific criteria, each of which must be met to qualify as a resource or reserve, respectively. These criteria, such as
demonstration of economic viability, points of reference and grade, are specific and attainable. The QP and Company
management agree on the reasonableness of the criteria for the purposes of estimating resources and reserves. Calculations
using these criteria are reviewed and validated by the QP.
Estimations and assumptions were developed independently for each significant mineral location. All estimates require a
combination of historical data and key assumptions and parameters. When possible, resources and data from generally accepted
industry sources, such as governmental resource agencies, were used to develop these estimations.
Geological modeling and mine planning efforts serve as a base assumption for resource estimates at each significant coal
mining operation. These outputs have been prepared by both Company personnel and third parties, and the methodology is
36
compared to industry best practices. Mine planning decisions are determined and agreed upon by Company management.
Management adjusts forward-looking models by reference to historic mining results, including by reviewing actual versus
predicted levels of production from the mineral deposit, and if necessary, re-evaluating mining methodologies if production
outcomes were not realized as predicted. Ongoing mining of the mineral deposit, coupled with product quality validation
pursuant to industry best practices and customer expectations, provides further empirical evidence as to the homogeneity,
continuity and characteristics of the mineral resource. Ongoing quality validation of production also provides a means to
monitor for any potential changes in quality. Also, ongoing monitoring of ground conditions within the mine, surveying for
evidence of subsidence and other visible signs of deterioration that may signal the need to re-evaluate rock mechanics and
structure of the mine ultimately inform extraction ratios and mine design, which underpin mineral reserve estimates.
Management also assesses risks inherent in mineral resource and reserve estimates, such as the accuracy of geophysical data
that is used to support mine planning, identify hazards and inform operations of the presence of mineable deposits. Also,
management is aware of risks associated with potential gaps in assessing the completeness of mineral extraction licenses,
entitlements or rights, or changes in laws or regulations that could directly impact the ability to assess mineral resources and
reserves or impact production levels. Risks inherent in overestimated reserves can impact financial performance when revealed,
such as changes in amortizations that are based on life of mine estimates.
Customer-owned Resources and Reserves
South Hallsville No. 1 Mine — The Sabine Mining Company
The South Hallsville No. 1 Mine generally produces between 1.5 million and 2.0 million tons of lignite annually. The mine
began delivering coal in 1985. All production from the mine is delivered to Southwestern Electric Power Company's
("SWEPCO") Henry W. Pirkey Plant (the "Pirkey Plant"). SWEPCO is an American Electric Power (“AEP”) company. The
mine's reserves and resources are owned and controlled by AEP. The Company conducts activities to extract these customer-
owned and controlled reserves.
During 2020, AEP announced its intent to retire the Pirkey Plant in 2023. SWEPCO expects deliveries from Sabine to continue
until the first quarter of 2023 at which time Sabine expects to begin final reclamation. Funding for mine reclamation is the
responsibility of SWEPCO.
The South Hallsville No. 1 Mine, operated by Sabine, is located approximately 150 miles east of Dallas, Texas on FM 968. The
entrance to the mine is by means of a paved road. Sabine has no title, claim, lease or option to acquire any of the reserves at the
South Hallsville No. 1 Mine. Southwestern Electric Power Company controls all of the reserves within the South Hallsville
No. 1 Mine.
Five Forks Mine — Demery Resources Company, LLC
The Five Forks Mine generally produces between 0.1 million and 0.3 million tons of lignite annually. The mine began
delivering coal in 2012 and is located approximately three miles north of Creston, Louisiana on State Highway 153. The mine's
reserves and resources are owned and controlled by the customer. The Company conducts activities to extract these customer-
owned and controlled reserves.
Access to the Five Forks Mine is by means of a paved road. Demery has no title, claim, lease or option to acquire any of the
reserves at the Five Forks Mine. Demery's customer, Five Forks Mining, LLC, controls all of the reserves within the Five Forks
Mine.
Facilities and Equipment
The facilities and equipment for each of the coal mines are maintained to allow for safe and efficient operation. The equipment
is well maintained, in good physical condition and is either updated or replaced periodically with newer models or upgrades
available to keep up with modern technology. As equipment wears out, the mines evaluate what replacement option will be the
most cost-efficient, including the evaluation of both new and used equipment, and proceed with that replacement.
37
The mining method and total cost of the property, plant and equipment, net of applicable accumulated amortization,
depreciation and impairment as of December 31, 2021 is set forth in the chart below:
Location
Mining Method
Total Historical Cost of Mine
Property, Plant and
Equipment
(excluding Coal Land, Real
Estate
and Construction in Progress),
Net of
Applicable Accumulated
Amortization, Depreciation
and Impairment
(in millions)
Unconsolidated Mining Operations
Freedom Mine — The Coteau Properties Company
Dragline operation with 3 draglines
Falkirk Mine — The Falkirk Mining Company
South Hallsville No. 1 Mine — The Sabine Mining
Company
Five Forks Mine — Demery Resources Company, LLC
Coyote Creek Mine — Coyote Creek Mining Company,
LLC
Consolidated Mining Operations
Dragline operation with 4 draglines
Dragline operation with 4 draglines
Truck-shovel operation (a)
Dragline operation with 1 dragline
Red Hills Mine — Mississippi Lignite Mining Company
Dragline operation with 1 dragline
Other
N/A
$
$
$
$
$
$
$
(a) Predominantly all of Demery's machinery and equipment is owned by its customer.
NAMining Segment - Operations
96.2
93.8
59.3
—
131.7
67.9
1.2
NAMining provides contract mining services for independently owned mines and quarries, primarily operating and maintaining
draglines at limestone quarries and utilizing other mining equipment at sand and gravel quarries. During 2021, NAMining
operated 32 draglines and other equipment at 25 quarries. Of the 32 draglines, 9 are owned by the Company and 23 are owned
by customers. At December 31, 2021, NAMining had $35.5 million in property, plant and equipment, net of applicable
accumulated amortization, depreciation and impairment.
38
The mining process at the limestone mines involves excavating limestone from a water-filled quarry utilizing draglines. The
excavated limestone is transported and processed by the customer. The following mines were operational during 2021:
Location Name
White Rock — North
Krome
Alico
FEC
SCL
Card Sound
Central State Aggregates
Mid Coast Aggregates
West Florida Aggregates
St. Catherine
Center Hill
Inglis
Titan Corkscrew
Palm Beach Aggregates
Perry
SDI Aggregates
Queensfield
County Line (a)
Newberry
Titan Pennsuco
Seven Diamonds
Johnson County
Little River
Rosser
Aggregate
Limestone
Limestone
Limestone
Limestone
Limestone
Limestone
Limestone
Limestone
Limestone
Limestone
Limestone
Limestone
Limestone
Limestone
Limestone
Limestone
Location
Miami
Miami
Ft. Myers
Miami
Miami
Florida City
Zephyrhills
Sumter County
Hernando County
Sumter County
Sumter County
Crystal River
Ft. Myers
Loxahatchee
Lamont
Florida City
Sand and gravel
King William County
VA
Limestone
Pasco County
Limestone
Limestone
Limestone
Alachua County
Miami
Pasco County
Sand and gravel
Johnson County
Sand and gravel
Sand and gravel
Ashdown
Ennis
State
FL
Customer
WRQ
Year NACCO
Started
Operations
1995
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
FL
IN
AR
TX
FL
Cemex
Cemex
Cemex
Cemex
Cemex
McDonald Group
McDonald Group
McDonald Group
Cemex
Cemex
Cemex
Titan America
Palm Beach Aggregates
Martin Marietta
Blue Water Industries
King William Sand and
Gravel Company, Inc.
K&M Pasco 130 Holdings,
LLC
Argos USA, LLC
Titan America
Seven Diamonds, LLC
Martin Marietta
Lehigh Hanson
Lehigh Hanson
Cemex
2003
2004
2005
2006
2009
2016
2016
2016
2016
2016
2016
2017
2017
2018
2018
2018
2019
2019
2020
2021
2021
2021
2021
2021
Brooksville Cement Plant
Limestone
Brooksville
(a) The County Line contract was terminated during the third quarter of 2021. NAMining mined 0.1 million and 0.2 million tons of limestone
at this location during the 2021 and 2020 periods, respectively.
NAMining's customers control all of the limestone and sand reserves within their respective mines. NAMining has no title,
claim, lease or option to acquire any of the reserves at any of the mines where it provides services.
Access to the White Rock mine is by means of a paved road from 122nd Avenue.
Access to the Krome mine is by means of a paved road from Krome Avenue.
Access to the Alico mine is by means of a paved road from Alico Road.
Access to the FEC mine is by means of a paved road from NW 118th Avenue.
Access to the SCL mine is by means of a paved road from NW 137th Avenue.
Access to the Card Sound mine is by means of a paved road from SW 408th Street.
Access to the Central State Aggregates mine is by means of a paved road from Yonkers Boulevard.
Access to the Mid Coast Aggregates mine is by means of a paved road from State Road 50.
Access to the West Florida Aggregates mine is by means of a paved road from Cortez Boulevard.
Access to the St. Catherine mine is by means of a paved road from County Road 673.
Access to the Center Hill mine is by means of a paved road from West Kings Highway.
39
Access to the Inglis mine is by means of a paved road from Highway 19 South.
Access to the Titan Corkscrew mine is by means of a paved road from Corkscrew Road.
Access to the Palm Beach Aggregates mine is by means of a paved road from State Road 80.
Access to the Perry mine is by means of paved road from Nutall Rise Road.
Access to the SDI Aggregates mine is by means of paved road from SW 167th AVE.
Access to the Queensfield Mine is by means of paved road from Dabney's Mill Road (SR 604).
Access to the County Line mine is by means of paved road from 18744 County Line Road.
Access to the Newberry mine is by means of paved road from NW County Road 235 (CR 235).
Access to the Titan Pennsuco mine is by means of a paved road from NW 121st Way.
Access to the Seven Diamonds mine is by means of a paved road from US-41 S/Broad St.
Access to the Johnson County mine is by means of a paved road from Old State 37/N Waverly Park Road.
Access to the Little River mine is by means of an unpaved road from Little River 60.
Access to the Rosser mine is by means of a paved road from TX-34 S.
Access to Brooksville Cement plant is by means of a paved road from Cement Plant Road.
Minerals Management - Operations
As an owner of royalty and mineral interests, the Company’s access to information concerning activity and operations of its
royalty and mineral interests is limited. The Company does not have information that would be available to a company with oil
and natural gas operations because detailed information is not generally available to owners of royalty and mineral interests.
Consequently, the exact number of wells producing from or drilling on the Company’s mineral interests at a given point in time
is not determinable. The following table sets forth the Company’s estimate of the number of gross and net productive wells as
of December 31, 2021:
Oil
Natural Gas
Total
Gross
Net
467
398
865
0.9
11.4
12.3
Gross wells are the total wells in which an interest is owned.
Net wells are calculated based on the Company's net royalty interest, factoring in both ownership percentage of gross wells and
royalty rate.
The majority of the Company’s producing mineral and royalty interest acreage now, or in the future, can be pooled with third-
party acreage to form pooled units. Pooling proportionately reduces the Company’s royalty interest in wells drilled in a pooled
unit, and it proportionately increases the number of wells in which the Company has such reduced royalty interest.
40
The following table includes the Company's estimate of acreage for oil and gas mineral interests, NPRIs, and ORRIs as of
December 31, 2021:
Appalachia
East Texas/Haynesville
Permian
Eagle Ford
Other
Total
Gross Acres
Net Royalty Acres
34,661
6,477
63,998
15,510
7,139
127,785
36,199
7,455
1,243
1,712
13,327
59,936
The Company may own more than one type of interest in the same tract of land, but the overlap is not significant. Net Royalty
Acres are calculated based on the Company’s ownership and royalty rate, normalized to a standard 1/8th royalty lease, and
assumes a 1/4th royalty rate for unleased acres.
The following table includes the Company's estimate of developed and undeveloped acreage based on the gross acres in a basin
or region and includes mineral interests, NPRIs, and ORRIs as of December 31, 2021:
Appalachia
East Texas/Haynesville
Permian
Eagle Ford
Other
Total
Developed Acreage
Undeveloped
Acreage
Gross Acreage
28,011
5,253
62,496
15,510
1,021
112,291
6,650
1,224
1,503
0
6,118
15,495
34,661
6,477
63,998
15,510
7,139
127,785
Undeveloped acres are either unleased and open or are leased acres on which wells have not been drilled or completed to a
point that would permit the production of commercial quantities of oil or natural gas, regardless of whether such acreage
contains proved reserves.
Production and Price History
The following table sets forth the estimated oil and natural gas production data related to the Company’s mineral and royalty
interests as well as certain price and cost information for the years ended December 31:
Production data:
Oil (bbl) (1)
NGL (bbl) (1)
Residue gas (Mcf) (2)
Total BOE (3)
Average realized prices:
Oil (bbl) (1)
NGL (bbl) (1)
Residue gas (Mcf) (2)
Average unit cost
BOE (3)
2021 (4)
2020
32,627
63,559
6,225,422
1,133,756
66.87 $
29.33 $
3.36 $
4.99 $
2,239
68,599
7,981,545
1,401,095
36.27
14.56
1.87
6.01
$
$
$
$
(1) Bbl. One stock tank barrel, or 42 U.S. gallons liquid volume.
41
(2) Mcf. One thousand cubic feet of natural gas at the contractual pressure and temperature bases.
(3) BOE. Barrel of Oil Equivalent, a conversion factor of 6 MCF of gas was used for 1 equivalent bbl of oil.
(4) As an owner of mineral and royalty interests, the Company’s access to information concerning activity and operations of its
royalty and mineral interests is limited. As a result, the Company estimated the last two months of 2021 production and pricing data
using projections based on decline rates of wells and prior expense information.
Evaluation and Review of Reserves
The reserves estimates as of December 31, 2021 were prepared by Haas Petroleum Engineering Services, Inc. ("Haas
Engineering"). Haas Engineering has provided reservoir engineering services, consulting and ongoing support for major and
independent petroleum companies, public utilities, financial institutions, investors, and government agencies since 1980. Haas
Engineering does not own an interest in NACCO or any of the Company's properties, nor is it employed on a contingent basis.
A copy of Haas Engineering's estimated proved reserve report as of December 31, 2021 is incorporated by reference herein to
Exhibit 99.1 to this Form 10-K.
The properties evaluated are located in Alabama, Louisiana, Ohio, Pennsylvania, and Texas and represent all of the Company’s
oil and gas reserves. A reserves audit is not the same as a financial audit. Reserve engineering is a subjective process of
estimating volumes of economically recoverable oil and natural gas that cannot be measured in an exact manner. The accuracy
of any reserve estimate is a function of the quality of available data and of engineering and geological interpretation. As a
result, the estimates of different engineers often vary. In addition, the results of drilling, testing, and production may justify
revisions of such estimates. Accordingly, reserve estimates often differ from the quantities of oil and natural gas that are
ultimately recovered. Estimates of economically recoverable oil and natural gas and of future net revenues are based on several
variables and assumptions, all of which may vary from actual results, including geologic interpretation, prices, and future
production rates and costs.
The reserves estimates have been prepared using standard engineering practices generally accepted by the petroleum industry.
Decline curve analysis was used to estimate the remaining reserves of pressure depletion reservoirs with enough historical
production data to establish decline trends. Reservoirs under non-pressure depletion drive mechanisms and non-producing
reserves were estimated by volumetric analysis, research of analogous reservoirs, or a combination of both. Reserves have been
estimated using deterministic and probabilistic methods. The appropriate methodology was used, as deemed necessary, to
estimate reserves in conformance with SEC regulations. The maximum remaining reserves life assigned to wells included in
this report is 50 years.
Total net proved reserves are defined as those natural gas and hydrocarbon liquid reserves to the Company's interests after
deducting all royalties, overriding royalties, and reversionary interests owned by outside parties that become effective upon
payout of specified monetary balances. All reserves estimates have been prepared using standard engineering practices
generally accepted by the petroleum industry and conform to guidelines developed and adopted by the SEC.
Technologies Used in Reserve Estimation
The SEC’s reserves rules allow the use of techniques that have been proved effective by actual production from projects in the
same reservoir or an analogous reservoir or by other evidence using reliable technology that establishes reasonable certainty.
The term “reasonable certainty” implies a high degree of confidence that the quantities of oil, natural gas and/or NGLs actually
recovered will equal or exceed the estimate. To achieve reasonable certainty, the Company employed technologies that have
been demonstrated to yield results with consistency and repeatability. The technologies and economic data used in the
estimation of the Company’s proved reserves include, but are not limited to, well logs, geologic maps, seismic data, well test
data, production data, historical price and cost information and property ownership interests. The accuracy of the estimates of
the Company’s reserves is a function of:
•
•
•
•
the quality and quantity of available data and the engineering and geological interpretation of that data;
estimates regarding the amount and timing of future operating costs, development costs and workovers, all of which
may vary considerably from actual results;
future prices of oil, natural gas and NGLs, which may vary considerably from those estimated; and
the judgment of the persons preparing the estimates.
42
The following table presents the Company's estimated net proved oil and natural gas reserves as of December 31, 2021 based
on the reserve report prepared by Haas Engineering, the Company’s independent petroleum engineering firm. All of the
Company’s reserves are located in the United States.
Proved developed
Proved undeveloped
Total
Oil (bbl) (1)
Net reserves as of December 31, 2021
NGL (bbl) (1)
Residue gas (Mcf) (2)
167,430
220
167,650
282,230
90
282,320
16,617,360
1,210
16,618,570
(1) Bbl. One stock tank barrel, or 42 U.S. gallons liquid volume.
(2) Mcf. One thousand cubic feet of natural gas at the contractual pressure and temperature bases.
As an owner of mineral and royalty interests and not working interests, the Company is not required to make capital
expenditures and did not make capital expenditures to convert proved undeveloped reserves from undeveloped to developed.
Internal Control Disclosure
The Company's internal staff works closely with Haas Engineering to ensure the integrity, accuracy and timeliness of the data
used to calculate proved reserves relating to NACCO's assets. Internal technical team members met with independent reserve
engineers periodically during the period covered by the reserves report to discuss the assumptions and methods used in the
proved reserve estimation process.
The preparation of the Company's proved reserve estimates are completed in accordance with internal control procedures.
These procedures, which are intended to ensure reliability of reserve estimations, include the following:
•
•
•
•
•
Review and verification of historical production data, which data is based on actual production as reported by third-
party producers who lease the Company’s royalty and mineral interests;
Preparation of reserve estimates by Haas Engineering under the direct supervision of internal staff;
Review by the President of Catapult Mineral Partners of all of the Company's reported proved reserves at the close of
each quarter, including the review of all significant reserve changes;
Verification of property ownership by the Company's land department; and
No employee’s compensation is tied to the amount of reserves booked.
The Minerals Management Segment’s Business Operations Manager is the technical person primarily responsible for
overseeing the preparation of the internal reserve estimates and for coordinating with Haas Engineering in the preparation of the
third-party reserve report. The Business Operations Manager has over 10 years of industry experience with positions of
increasing responsibility and reports directly to the President of Catapult Mineral Partners, the Company’s business unit
focused on managing and expanding the Company’s portfolio of oil and gas mineral and royalty interests.
Headquarter locations
NACCO leases office space in Mayfield Heights, Ohio, a suburb of Cleveland, Ohio, which serves as its corporate
headquarters.
Coal Mining and Minerals Management lease corporate headquarters office space in Plano, Texas.
NAMining leases office and warehouse space in Medley, Florida.
Item 3. LEGAL PROCEEDINGS
Neither the Company nor any of its subsidiaries is a party to any material legal proceeding other than ordinary routine litigation
incidental to its respective business.
Item 4. MINE SAFETY DISCLOSURES
Information concerning mine safety violations or other regulatory matters required by Section 1503(a) of The Dodd-Frank Act
and Item 104 of Regulation S-K is included in Exhibit 95 filed with this Form 10-K.
43
PART II
Item 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND
ISSUER PURCHASES OF EQUITY SECURITIES
NACCO's Class A common stock is traded on the New York Stock Exchange under the ticker symbol “NC.” Because of
transfer restrictions, no trading market has developed, or is expected to develop, for the Company's Class B common stock. The
Class B common stock is convertible into Class A common stock on a one-for-one basis.
At December 31, 2021, there were 691 Class A common stockholders of record and 126 Class B common stockholders of
record.
Purchases of Equity Securities by the Issuer and Affiliated Purchasers
Issuer Purchases of Equity Securities (1)
(a)
Total
Number of
Shares
Purchased
(b)
Average
Price Paid
per Share
—
—
—
—
$
$
$
$
—
—
—
—
Period
October 1 to 31, 2021
November 1 to 30, 2021
December 1 to 31, 2021
Total
(c)
Total Number
of Shares
Purchased as
Part of the
Publicly
Announced
Program
(d)
Maximum
Number of Shares
(or Approximate
Dollar Value) that
May Yet Be
Purchased Under
the Program (1)
—
—
—
—
$
$
$
$
22,659,516
22,659,516
22,659,516
22,659,516
(1) On November 10, 2021, the Company's Board of Directors approved a stock purchase program ("2021 Stock Repurchase
Program") providing for the purchase of up to $20.0 million of the Company’s outstanding Class A common stock
through December 31, 2023. See Note 12 to the Consolidated Financial Statements in this Form 10-K for a discussion of
the Company's stock repurchase programs.
Item 6. SELECTED FINANCIAL DATA
As a “smaller reporting company” as defined by Rule 12b-2 of the Securities Exchange Act of 1934, the Company is not
required to provide this information.
44
Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
OVERVIEW
Management's Discussion and Analysis of Financial Condition and Results of Operations contains forward-looking statements
within the meaning of the Private Securities Litigation Reform Act of 1995. These statements are based upon management's
current expectations and are subject to various uncertainties and changes in circumstances. Important factors that could cause
actual results to differ materially from those described in these forward-looking statements are set forth below under the
heading “Forward-Looking Statements."
Management's Discussion and Analysis of Financial Condition and Results of Operations include NACCO Industries, Inc.®
(“NACCO” or the “Company”). NACCO brings natural resources to life by delivering aggregates, minerals, reliable fuels and
environmental solutions through its robust portfolio of NACCO Natural Resources businesses. The Company operates under
three business segments: Coal Mining, North American Mining ("NAMining") and Minerals Management. The Coal Mining
segment operates surface coal mines for power generation companies and an activated carbon producer. The NAMining
segment is a trusted mining partner for producers of aggregates, lithium and other minerals. The Minerals Management
segment, which includes the Catapult Mineral Partners (“Catapult”) business, acquires and promotes the development of
mineral interests. In addition, Mitigation Resources of North America® (“Mitigation Resources”) provides stream and wetland
mitigation solutions.
The Company has items not directly attributable to a reportable segment that are not included as part of the measurement of
segment operating profit, which primarily includes administrative costs related to public company reporting requirements at
the parent company and the financial results of Mitigation Resources and Bellaire Corporation ("Bellaire"). Bellaire manages
the Company’s long-term liabilities related to former Eastern U.S. underground mining activities.
All financial statement line items below operating profit (other income, including interest expense and interest income, the
provision for income taxes and net income) are presented and discussed within this Form 10-K on a consolidated basis.
See “Item 1. Business" beginning on page 1 in this Form 10-K for further discussion of NACCO's subsidiaries. Additional
information relating to financial and operating data on a segment basis (including unallocated items) is set forth in Note 15 to
the Consolidated Financial Statements contained in this Form 10-K.
CRITICAL ACCOUNTING POLICIES AND ESTIMATES
The Company's discussion and analysis of its financial condition and results of operations are based upon the Company's
consolidated financial statements, which have been prepared in accordance with U.S. generally accepted accounting principles.
The preparation of these financial statements requires the Company to make estimates and judgments that affect the reported
amounts of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities (if any). On an
ongoing basis, the Company evaluates its estimates based on historical experience, actuarial valuations and various other
assumptions that are believed to be reasonable under the circumstances, the results of which form the basis for making
judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results
may differ from those estimates.
The Company believes the following critical accounting policies affect its more significant judgments and estimates used in
the preparation of its consolidated financial statements.
Revenue recognition: Revenues are recognized when control of the promised goods or services is transferred to the
Company’s customers, in an amount that reflects the consideration the Company expects to be entitled to in exchange for those
goods or services. The Company accounts for revenue in accordance with Accounting Standards Codification ("ASC") Topic
606, "Revenue from Contracts with Customers." See Note 3 to the Consolidated Financial Statements in this Form 10-K for
further discussion of the Company's revenue recognition.
Long-lived assets: The Company periodically evaluates long-lived assets for impairment when changes in circumstances or
the occurrence of certain events indicate the carrying amount of an asset may not be recoverable. Upon identification of
indicators of impairment, the Company evaluates the carrying value of the asset by comparing the estimated future
undiscounted cash flows generated from the use of the asset and its eventual disposition with the asset's net carrying value. If
the carrying value of an asset is considered impaired, an impairment charge is recorded for the amount that the carrying value
45
Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
of the long-lived asset exceeds its fair value. Fair value is estimated as the price that would be received to sell an asset or paid
to transfer a liability in an orderly transaction between market participants at the measurement date.
The Company regularly performs reviews of potential future development projects and identified certain undeveloped
properties where market conditions related to any future development deteriorated during 2020. As a result, the Company
recognized charges of $7.3 million in the Minerals Management segment and $1.1 million in the Coal Mining segment to
write-off certain capitalized leasehold costs, prepaid royalties and other assets during 2020.
At MLMC, the costs of mining operations are not reimbursed by MLMC's customer. As such, increased costs at MLMC or
decreased revenues could materially reduce the Company's profitability. Any reduction in customer demand at MLMC,
including reductions related to reduced mechanical availability of the customer’s power plant, would adversely affect the
Company's operating results and could result in significant impairments. MLMC has approximately $136 million of long-lived
assets, including property, plant and equipment and its coal supply agreement intangible asset, which are subject to periodic
impairment analysis and review. Identifying and assessing whether impairment indicators exist, or if events or changes in
circumstances have occurred, including assumptions about future power plant dispatch levels, changes in operating costs and
other factors that impact anticipated revenue and customer demand, requires significant judgment. Actual future operating
results could differ significantly from these estimates, which may result in an impairment charge in a future period, which
could have a substantial impact on the Company’s results of operations.
Income taxes: Tax law requires certain items to be included in the tax return at different times than the items are reflected in
the financial statements. Some of these differences are permanent, such as expenses that are not deductible for tax purposes,
and some differences are temporary, reversing over time, such as depreciation expense. These temporary differences create
deferred tax assets and liabilities using currently enacted tax rates. The objective of accounting for income taxes is to
recognize the amount of taxes payable or refundable for the current year, and deferred tax liabilities and assets for the future
tax consequences of events that have been recognized in the financial statements or tax returns. The effect of a change in tax
rates on deferred tax assets and liabilities is recognized in the provision for income taxes in the period that includes the
enactment date. Management is required to estimate the timing of the recognition of deferred tax assets and liabilities, make
assumptions about the future deductibility of deferred tax assets and assess deferred tax liabilities based on enacted laws and
tax rates for the appropriate tax jurisdictions to determine the amount of such deferred tax assets and liabilities. Changes in the
calculated deferred tax assets and liabilities may occur in certain circumstances, including statutory income tax rate changes,
statutory tax law changes, or changes in the structure or tax status.
The Company's tax assets, liabilities, and tax expense are supported by historical earnings and losses and the Company's best
estimates and assumptions of future earnings. The Company assesses whether a valuation allowance should be established
against its deferred tax assets based on consideration of all available evidence, both positive and negative, using a more likely
than not standard. This assessment considers, among other matters, scheduled reversals of deferred tax liabilities, projected
future taxable income, tax-planning strategies, and results of recent operations. The assumptions about future taxable income
require significant judgment and are consistent with the plans and estimates the Company is using to manage the underlying
businesses. When the Company determines, based on all available evidence, that it is more likely than not that deferred tax
assets will not be realized, a valuation allowance is established.
Since significant judgment is required to assess the future tax consequences of events that have been recognized in the
Company's financial statements or tax returns, the ultimate resolution of these events could result in adjustments to the
Company's financial statements and such adjustments could be material. The Company believes the current assumptions,
judgments and other considerations used to estimate the current year accrued and deferred tax positions are appropriate. If the
actual outcome of future tax consequences differs from these estimates and assumptions, due to changes or future events, the
resulting change to the provision for income taxes could have a material impact on the Company's results of operations and
financial position.
See Note 13 to the Consolidated Financial Statements in this Form 10-K for further discussion of the Company's income taxes.
46
Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
CONSOLIDATED FINANCIAL SUMMARY
The results of operations for NACCO were as follows for the years ended December 31:
Revenues:
Coal Mining
NAMining
Minerals Management
Unallocated Items
Eliminations
Total revenue
Operating profit (loss):
Coal Mining
NAMining
Minerals Management
Unallocated Items
Eliminations
Total operating profit
Interest expense
Interest income
Closed mine obligations
Gain on equity securities
Other, net
Other income, net
Income before income tax provision (benefit)
Income tax provision (benefit)
Net income
Effective income tax rate
2021
2020
$ 91,851
69,924
31,003
4,695
(5,627)
$ 191,846
$ 49,059
109
26,080
(19,553)
(285)
$ 55,410
1,719
(449)
1,297
(3,423)
(584)
(1,440)
$ 72,088
42,392
14,721
2,133
(2,902)
$ 128,432
$ 25,436
1,872
3,493
(17,256)
(97)
$ 13,448
1,354
(1,200)
1,641
(1,226)
(1,379)
(810)
56,850
8,725
$ 48,125
14,258
(535)
$ 14,793
15.3 %
(3.8) %
The components of the change in revenues and operating profit are discussed below in "Segment Results."
Other income, net
Interest income decreased $0.8 million primarily due lower interest rates and a lower average invested cash balance during
2021 compared with 2020.
Gain on equity securities represents changes in the market price of invested assets reported at fair value. The change in 2021
compared with 2020 was due to fluctuations in the market prices of the underlying assets. See Note 9 to the Consolidated
Financial Statements in this Form 10-K for further discussion of the Company's invested assets reported at fair value.
North American Coal Corporation India Private Limited ("NACC India") was formed to provide technical business advisory
services to the third-party owner of a coal mine in India. During 2014, NACC India's customer defaulted on its contractual
payment obligations and as a result of this default, NACC India terminated its contract with the customer and began pursuing
contractual remedies. During 2020, the Company received a $1.0 million payment from NACC India's customer which has
been reported on the line, Other, net.
47
Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
Income Taxes
The Company recorded an income tax expense of $8.7 million for the year ended December 31, 2021 on income before
income tax of $56.9 million, or 15.3%, compared to income tax benefit of $0.5 million for the year ended December 31, 2020
on income before income tax of $14.3 million, or (3.8%). The income tax benefit for the year ended December 31, 2020
included $7.3 million of discrete tax charges primarily related to settlement of tax examinations, reserves for uncertain tax
positions and return to provision adjustments partially offset by a benefit of $4.7 million, primarily due to the rate differential
related to carrying back losses under the provisions of the Coronavirus Aid, Relief, and Economic Security Act ("CARES
Act"). The CARES Act allows net operating tax losses incurred in 2018, 2019, and 2020 to be carried back to each of the five
preceding taxable years to generate a refund of previously paid income taxes. The Company generated a net tax operating loss
in 2020 primarily due to the realization of certain deferred tax assets. There were no material discrete items affecting income
tax expense in 2021.
The effective income tax rate for 2021 reflects the impact of higher pre-tax income in 2021 compared with 2020, including the
termination fee associated with the Bisti contract termination. The effective income tax rate varies based upon the mix and
timing of earnings between entities that benefit from percentage depletion and those that do not benefit from percentage
depletion. The benefit from percentage depletion is not directly related to the amount of pre-tax income recorded in a period.
See Note 13 to the Consolidated Financial Statements in this Form 10-K for further discussion of the Company's income taxes.
LIQUIDITY AND CAPITAL RESOURCES
Cash Flows
The following tables detail the change in cash flow for the years ended December 31:
Operating activities:
Net income
Depreciation, depletion and amortization
Deferred income taxes
Stock-based compensation
Gain on sale of assets
Inventory impairment charge
Other asset impairment charge
Other
Working capital changes
Net cash provided by (used for) operating activities
Investing activities:
Expenditures for property, plant and equipment and acquisition of mineral
interests
Proceeds from the sale of assets
Other
Net cash used for investing activities
2021
2020
Change
$
48,125 $
14,793 $
33,332
23,085
(3,553)
5,561
(60)
—
—
1,973
18,114
7,517
3,078
(269)
1,973
8,359
(3,452)
(256)
(52,599)
74,875
(2,486)
4,971
(11,070)
2,483
209
(1,973)
(8,359)
5,425
52,343
77,361
(44,561)
(44,368)
633
571
(219)
(2,187)
(44,147)
(45,984)
(193)
62
1,968
1,837
Cash flow before financing activities
$
30,728 $
(48,470) $
79,198
48
Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
The $77.4 million increase in net cash provided by (used for) operating activities was primarily the result of favorable working
capital changes and an increase in net income. Working capital changes primarily included:
•
•
Decreased payments made under deferred compensation and long-term incentive compensation plans in 2021
compared with 2020.
An increase in Accounts payable during 2021 compared with a decrease in Accounts payable during 2020 due to
timing of payments.
Financing activities:
Net (reductions) additions to long-term debt and revolving credit agreements
$
(25,801) $
20,073 $
(45,874)
2021
2020
Change
Cash dividends paid
Other
(5,617)
(1,755)
(5,375)
(242)
(670)
(1,085)
Net cash (used for) provided by financing activities
$
(33,173) $
14,028 $
(47,201)
The change in net cash (used for) provided by financing activities was primarily due to repayments during 2021 compared
with borrowings during 2020.
Financing Activities
Financing arrangements are obtained and maintained at the subsidiary level. NACoal has a secured revolving line of credit of
up to $150.0 million (the “NACoal Facility”) that expires in November 2025. Borrowings outstanding under the NACoal
Facility were $4.0 million at December 31, 2021. At December 31, 2021, the excess availability under the NACoal Facility
was $116.2 million, which reflects a reduction for outstanding letters of credit of $29.8 million.
NACCO has not guaranteed any borrowings of NACoal. The borrowing agreements at NACoal allow for the payment to
NACCO of dividends and advances under certain circumstances. Dividends (to the extent permitted by NACoal's borrowing
agreement) and management fees are the primary sources of cash for NACCO and enable the Company to pay dividends to
stockholders.
The NACoal Facility has performance-based pricing, which sets interest rates based upon NACoal achieving various levels of
debt to EBITDA ratios, as defined in the NACoal Facility. Borrowings bear interest at a floating rate plus a margin based on
the level of debt to EBITDA ratio achieved. The applicable margins, effective December 31, 2021, for base rate and LIBOR
loans were 1.25% and 2.25%, respectively. The NACoal Facility has a commitment fee which is based upon achieving various
levels of debt to EBITDA ratios. The commitment fee was 0.35% on the unused commitment at December 31, 2021. During
the year ended December 31, 2021, the average borrowing under the NACoal Facility was $20.5 million and the weighted-
average annual interest rate was 2.1%.
The NACoal Facility contains restrictive covenants, which require, among other things, NACoal to maintain a maximum net
debt to EBITDA ratio of 2.75 to 1.00 and an interest coverage ratio of not less than 4.00 to 1.00. The NACoal Facility provides
the ability to make loans, dividends and advances to NACCO, with some restrictions based on maintaining a maximum debt to
EBITDA ratio of 1.50 to 1.00, or if greater than 1.50 to 1.00, a Fixed Charge Coverage Ratio of 1.10 to 1.00, in conjunction
with maintaining unused availability thresholds of borrowing capacity, as defined in the NACoal Facility, of $15.0 million. At
December 31, 2021, NACoal was in compliance with all financial covenants in the NACoal Facility.
The obligations under the NACoal Facility are guaranteed by certain of NACoal's direct and indirect, existing and future
domestic subsidiaries, and is secured by certain assets of NACoal and the guarantors, subject to customary exceptions and
limitations.
The Company believes funds available from cash on hand, the NACoal Facility and operating cash flows will provide
sufficient liquidity to meet its operating needs and commitments arising during the next twelve months and until the expiration
of the NACoal Facility in November 2025.
49
Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
Expenditures for property, plant and equipment and mineral interests
Following is a table which summarizes actual and planned expenditures (in millions):
NACCO
Planned
2022
Actual
2021
Actual
2020
$
68.0 $
44.6 $
44.4
Planned expenditures for 2022 are expected to be approximately $27 million in the NAMining segment, $22 million in the
Coal Mining segment, $10 million in the Minerals Management segment and up to $9 million at Mitigation Resources.
In the Coal Mining segment, elevated levels of expected capital expenditures through 2022 are primarily related to spending at
MLMC as it develops a new mine area. In the NAMining segment, expected capital expenditures through 2022 are primarily
for the acquisition, relocation and refurbishment of draglines as well as the acquisition of other mining equipment to support
the expansion of contract mining services beyond NAMining's historical dragline-oriented model, including the acquisition of
equipment to support Thacker Pass.
Expenditures are expected to be funded from internally generated funds and/or bank borrowings.
Capital Structure
NACCO's consolidated capital structure is presented below:
Cash and cash equivalents
Other net tangible assets
Intangible assets, net
Net assets
Total debt
Closed mine obligations
Total equity
Debt to total capitalization
December 31
2021
2020
Change
$ 86,005
$ 88,450
$
(2,445)
276,733
244,907
31,774
35,330
394,512
368,687
(20,710)
(46,465)
(21,686)
$ 352,116
(21,598)
$ 300,624
$
31,826
(3,556)
25,825
25,755
(88)
51,492
6 %
13 %
(7) %
The increase in other net tangible assets was primarily due to an increase in Property, plant and equipment including mineral
interests and Other non-current assets at December 31, 2021 compared with December 31, 2020. The increase in Other non-
current assets is primarily due to an increase in pension assets and deferred financing fees as well as an increase in the market
price of invested assets reported at fair value.
Contractual Obligations, Contingent Liabilities and Commitments
Pension and postretirement funding can vary significantly each year due to plan amendments, changes in the market value of
plan assets, legislation and the Company’s decisions to contribute above the minimum regulatory funding requirements. The
Company does not expect to contribute to its pension plan in 2022. NACCO maintains one supplemental retirement plan that
pays monthly benefits to participants directly out of corporate funds and expects to pay benefits of approximately $0.5 million
per year from 2022 through 2031. Benefit payments beyond that time cannot currently be estimated. NACCO also expects to
make payments related to its other postretirement plans of approximately $0.2 million per year from 2022 through 2031.
Benefit payments beyond that time cannot currently be estimated. All other pension benefit payments are made from assets of
the pension plan.
50
Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
NACCO has asset retirement obligations. See Note 7 to the Consolidated Financial Statements in this Form 10-K for further
discussion of the Company's asset retirement obligations.
NACCO has leases. See Note 10 to the Consolidated Financial Statements in this Form 10-K for further information on the
Company's leases.
NACCO has unrecognized tax benefits, including interest and penalties. See Note 13 to the Consolidated Financial Statements
in this Form 10-K for further discussion of the Company's income taxes.
NACoal is a party to certain guarantees related to Coyote Creek. The Company believes that the likelihood of NACoal’s future
performance under the guarantees is remote, and no amounts related to these guarantees have been recorded. See Note 17 to
the Consolidated Financial Statements in this Form 10-K for further discussion of the Company's guarantees.
The Company utilizes letters of credit to support commitments made in the ordinary course of business. As of December 31,
2021 and 2020, outstanding letters of credit totaled $29.8 million and $3.0 million, respectively. The increase in outstanding
letters of credit in 2021 is primarily due to the issuance of $20.0 million letters of credit to collateralize a portion of
outstanding surety bonds used to guarantee performance of consolidated mine reclamation obligations.
ENVIRONMENTAL MATTERS
The Company is affected by the regulations of numerous agencies, particularly the Federal Office of Surface Mining, the U.S.
Environmental Protection Agency, the U.S. Army Corps of Engineers and associated state regulatory authorities. In addition,
the Company closely monitors proposed legislation and regulation concerning SMCRA, CAA, ACE, CWA, RCRA, CERCLA
and other regulatory actions.
Compliance with these increasingly stringent regulations could result in higher expenditures for both capital improvements
and operating costs. The Company’s policies stress environmental responsibility and compliance with these regulations. Based
on current information, management does not expect compliance with these regulations to have a material adverse effect on
the Company’s financial condition or results of operations. See Item 1 in Part I of this Form 10-K for further discussion of
these matters.
SEGMENT RESULTS
COAL MINING SEGMENT
FINANCIAL REVIEW
See “Item 2. Properties" on page 31 in this Form 10-K for discussion of the Company's mineral resources and mineral
reserves.
Tons of coal delivered by the Coal Mining segment were as follows for the years ended December 31:
Unconsolidated mines
Consolidated mines
Total tons delivered
2021
2020
28,052
3,025
31,077
28,486
2,538
31,024
51
Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
The results of operations for the Coal Mining segment were as follows for the years ended December 31:
Revenues
Cost of sales
Gross profit
Earnings of unconsolidated operations(a)
Contract termination settlement
Selling, general and administrative expenses
Amortization of intangible assets
Loss (gain) on sale of assets
Operating profit
2021
2020
$
91,851 $
79,167
12,684
56,982
10,333
27,363
3,556
21
72,088
70,452
1,636
56,584
—
30,216
2,572
(4)
$
49,059 $
25,436
(a) See Note 17 to the Consolidated Financial Statements in this Form 10-K for a discussion of the Company's unconsolidated
subsidiaries, including summarized financial information.
2021 Compared with 2020
Revenues increased 27.4% in 2021 compared with 2020 primarily due to an increase in customer demand and tons delivered at
MLMC. Also contributing to the change was the recognition of reclamation revenue from Caddo Creek. During the fourth
quarter of 2020, Caddo Creek entered into a contract with a subsidiary of Advanced Emissions Solutions to perform mine
reclamation. As a result of these changes, Caddo Creek financial results are consolidated within the Coal Mining segment.
The following table identifies the components of change in operating profit for 2021 compared with 2020:
2020
Increase (decrease) from:
Contract termination settlement
Gross profit, excluding MLMC's 2020 inventory impairment charge
MLMC 's inventory impairment charge during 2020
Voluntary separation program ("VSP") charge during 2020
Selling, general and administrative expenses, excluding VSP charge
Earnings of unconsolidated operations
Amortization of intangibles
Net change on sale of assets
2021
Operating Profit
25,436
$
10,333
9,075
1,973
1,475
1,378
398
(984)
(25)
49,059
$
Operating profit increased $23.6 million in 2021 compared with 2020. The change in operating profit was primarily due to:
•
•
•
The $10.3 million payment recognized during 2021 related to the Bisti contract termination.
An increase in gross profit due to an increase in the profit per ton delivered at MLMC and earnings associated with
the reclamation contract at Caddo Creek. In addition, 2020 included certain costs associated with the termination of
the Camino Real Fuels, LLC contract mining agreement and higher outside service expenses at Centennial Natural
Resources.
The following items recognized in the prior year did not recur in 2021:
◦
A $2.0 million inventory impairment charge at MLMC as mining costs exceeded net realizable value.
52
Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
◦ A charge of $1.5 million related to one-time termination benefits as a result of a voluntary separation
program for employees who met certain age and service requirements to reduce overall headcount.
A $1.1 million asset impairment charge included in selling, general and administrative expenses in the table
above.
◦
•
In addition, selling, general and administrative expenses in 2021 include a decrease in employee-related costs and
professional service expenses, both partially offset by higher insurance expense. Included in insurance expense is an
increase of $1.3 million that is reimbursed by one of the Unconsolidated Subsidiaries. The offsetting income related
to the reimbursement is included in Earnings of unconsolidated operations.
NORTH AMERICAN MINING ("NAMining") SEGMENT
FINANCIAL REVIEW
Aggregate tons delivered by the NAMining segment were as follows for the years ended December 31:
Unconsolidated operations
Consolidated operations
Total tons delivered
2021
2020
9,938
42,565
52,503
9,367
36,546
45,913
The results of operations for the NAMining segment were as follows for the years ended December 31:
Total revenues
Reimbursable costs
Revenues excluding reimbursable costs
Revenues
Cost of sales
Gross profit
Earnings of unconsolidated operations(a)
Selling, general and administrative expenses
Gain on sale of assets
Operating profit
2021
2020
69,924 $
51,028
18,896 $
42,392
26,893
15,499
69,924 $
67,078
2,846
3,861
6,610
(12)
109 $
42,392
39,266
3,126
3,619
5,138
(265)
1,872
$
$
$
$
(a) See Note 17 to the Consolidated Financial Statements in this Form 10-K for a discussion of the Company's unconsolidated
subsidiaries, including summarized financial information.
2021 Compared with 2020
Total revenues increased 64.9% in 2021 compared with 2020 primarily due to a $24.1 million increase in reimbursable costs,
which have an offsetting amount in cost of sales and have no impact on operating profit. The relocation of draglines related to
new and amended contracts is the main driver of the increase in reimbursable costs. The increase in revenues excluding
reimbursable costs is primarily due to an increase in customer demand and tons delivered.
53
Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
The following table identifies the components of change in operating profit for 2021 compared with 2020.
2020
Increase (decrease) from:
Selling, general and administrative expenses
Gross profit
Net change on sale of assets
Earnings of unconsolidated operations
2021
Operating Profit
1,872
$
(1,472)
(280)
(253)
242
109
$
Operating profit decreased $1.8 million in 2021 compared with 2020 primarily due to an increase in selling, general and
administrative expenses, mainly attributable to higher employee-related costs, which include an increase in business
development expenses.
MINERALS MANAGEMENT SEGMENT
FINANCIAL REVIEW
The results of operations for the Minerals Management segment were as follows for the years ended December 31:
Revenues
Cost of sales
Gross profit
Selling, general and administrative expenses
Gain on sale of assets
Operating profit
2021 Compared with 2020
2021
2020
$
31,003 $
14,721
2,988
28,015
2,004
(69)
2,342
12,379
8,886
—
$
26,080 $
3,493
Revenues and operating profit increased in 2021 compared with 2020 primarily due to royalty income generated by gas
production from the Ohio and Louisiana mineral interests, as well as oil production from the Permian Basin and Eagle Ford
Shale mineral interests acquired late in the fourth quarter of 2020 and early in the second quarter of 2021, respectively.
Favorable changes in natural gas and oil prices also contributed to the improvement in revenues and operating profit. In
addition, the Company recognized $3.6 million of settlement income during 2021.
The decrease in selling, general and administrative expenses is primarily due to the absence of a $7.3 million asset impairment
charge recognized in 2020. The Company regularly performs reviews of potential future development projects and identified
certain undeveloped properties where market conditions related to any future development deteriorated during 2020. As a
result, the Company wrote-off certain capitalized leasehold costs and prepaid royalties related to legacy coal interests in 2020.
54
Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
UNALLOCATED ITEMS AND ELIMINATIONS
FINANCIAL REVIEW
Unallocated Items and Eliminations were as follows for the years ended December 31:
Operating loss
2021 Compared with 2020
2021
2020
$
(19,838) $
(17,353)
The operating loss increased during 2021 compared with 2020 primarily due to higher employee-related costs and an increase
in expenses related to business development initiatives.
During the fourth quarter of 2020, the Company implemented a voluntary separation program for employees who met certain
age and service requirements to reduce overall headcount. As a result of this program, the 2020 operating loss includes a
charge of $0.3 million related to one-time termination benefits.
NACCO Industries, Inc. Outlook
Coal Mining Outlook
As previously announced, GRE entered into an agreement to sell Coal Creek Station and the adjacent high-voltage direct
current transmission line to Bismarck, North Dakota-based Rainbow Energy. The closing of this sale is expected to occur in
the second quarter of 2022. Upon completion of the sale of Coal Creek Station, the existing agreements between GRE and
Falkirk will terminate. GRE will pay the Company $14.0 million, as well as transfer ownership of an office building and
convey membership units in Midwest AgEnergy to wholly owned and consolidated subsidiaries of NACCO.
Upon closing of the sale to Rainbow Energy, a new Coal Sales Agreement ("CSA") between Falkirk and Rainbow Energy will
become effective and Falkirk will continue supplying all coal requirements of Coal Creek Station. Falkirk will be paid a
management fee per ton of coal delivered for operating the mine, and Rainbow Energy will be responsible for funding all mine
operating costs and directly or indirectly providing all of the capital required to operate the mine. The CSA specifies that
Falkirk will perform final mine reclamation, which will be funded in its entirety by Rainbow Energy. The initial production
period is expected to run ten years from the effective date of the CSA, but the CSA may be extended or terminated early under
certain circumstances.
Coal Mining operating profit in 2022 is expected to decrease significantly compared with 2021. This expected decrease is
primarily the result of a decrease in coal deliveries from 2021 levels, as well as the termination of the Bisti contract. An
anticipated increase in operating expenses primarily due to expected higher insurance costs and other professional fees is also
expected to contribute to the reduction in operating profit.
Results at the consolidated mining operations are expected to decrease significantly in 2022 from 2021 primarily due to
expected substantially lower earnings at MLMC driven by an anticipated reduction in customer demand from 2021 levels,
which contributes to an increase in the cost per ton. Cost inflation on repairs, supplies and diesel fuel, and higher depreciation
expense related to recent capital expenditures to develop a new mine area will also contribute to the increase in the cost per ton
in 2022. In general, cost per ton delivered is lowest when the power plant requires a consistently high level of coal deliveries,
primarily because costs are spread over more tons.
The reduction in earnings at the unconsolidated Coal Mining operations is expected to be mainly driven by lower earnings at
Falkirk resulting in part from a planned power plant outage prior to the expected closure of the Rainbow Energy transaction. In
addition, to support the transfer of Coal Creek Station, Falkirk has agreed to a reduction in the current per ton management fee
from the effective date of the new CSA with Rainbow Energy through May 31, 2024. After May 31, 2024, Falkirk's per ton
management fee increases to a higher base in line with current fee levels, and thereafter adjusts annually according to an index
55
Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
which tracks a broad measure of U.S. inflation. Termination of the Bisti contract in late 2021 will also contribute to a decline
in the earnings at the unconsolidated mining operations in 2022.
Segment adjusted EBITDA, which excludes the termination payments of $10.3 million from Bisti's customer in 2021 and the
anticipated $14 million contract termination fee from GRE in 2022, is expected to decrease significantly in 2022 from 2021
primarily as a result of the forecasted reduction in operating profit partially offset by an increase in depreciation, depletion and
amortization expense. The increase in depreciation, depletion and amortization expense is primarily due to higher capital
expenditures at MLMC as a result of the development of a new mine area.
Capital expenditures are expected to be approximately $22 million in 2022. The elevated levels of capital expenditures from
2019 through 2022 relate to the necessary development of a new mine area at MLMC, which will allow continued coal
deliveries through the end of the contract. The increase in capital expenditures associated with mine development will result in
higher depreciation expense in future periods that will unfavorably affect future operating profit. Capital expenditures for
MLMC are expected to decline significantly beginning in 2023.
The Company's contract structure at each of its coal mining operations eliminates exposure to spot coal market price
fluctuations. However, fluctuations in natural gas prices and the availability of renewable generation, particularly wind, can
contribute to changes in power plant dispatch and customer demand for coal. The significant increase in natural gas prices in
2021 contributed to an increase in customer power plant dispatch and coal deliveries in 2021 over 2020. Sustained higher
natural gas prices could lead to increased demand for coal and positively affect the Coal Mining segment results in 2022.
Changes to expectations for customer power plant dispatch could affect the Company’s outlook for 2022 and over the longer
term. The owner of the power plant served by the Company's Sabine Mine in Texas intends to retire the power plant in the first
quarter of 2023, at which time Sabine expects to begin final reclamation. Funding for mine reclamation is the responsibility of
the customer. Coteau operates the Freedom Mine in North Dakota. All coal production from the Freedom Mine is delivered to
Basin Electric Power Cooperative. Basin Electric utilizes the coal at the Great Plains Synfuels Plant, Antelope Valley Station
and Leland Olds Station. The Synfuels Plant is a coal gasification plant owned by Dakota Gas that manufactures synthetic
natural gas and produces fertilizers, solvents, phenol, carbon dioxide and other chemical products for sale. In August 2021,
Basin Electric announced that it signed a non-binding term sheet which contemplates the sale of the assets of Dakota Gas. As
part of the announcement, Basin Electric indicated that the Synfuels Plant will continue existing operations through 2025. The
closing is subject to the satisfaction of specified conditions. Basin Electric is also considering other options for the Synfuels
Plant if the transaction with the potential buyer does not close.
NAMining Outlook
In 2022, NAMining expects full-year operating profit to increase significantly over 2021 due to an expected increase in
customer requirements and contributions from contracts executed during 2021. Segment adjusted EBITDA for 2022 is
expected to increase significantly compared with the prior year as a result of the improvement in operating profit and an
increase in depreciation expense.
During 2021, NAMining expanded its geographic footprint by entering into new contract mining services agreements at
quarries in Indiana, Texas and Arkansas. In addition, NAMining entered into a 15-year mining services contract with a new
customer at a limestone quarry in Central Florida. Presently, NAMining is operating two smaller draglines at this quarry while
it relocates a larger dragline that will significantly increase production capacity once commissioned, which is expected to
occur in the second half of 2022. NAMining also amended a contract with a current customer to provide additional services at
a limestone quarry in Florida. NAMining continues to have a substantial pipeline of potential new projects and is pursuing a
number of growth initiatives that, if successful, would be accretive to future earnings.
In 2019, NAMining's subsidiary, Sawtooth Mining, LLC, entered into a mining services agreement to serve as the exclusive
contract miner for the Thacker Pass lithium project in northern Nevada, owned by Lithium Nevada Corp., a subsidiary of
Lithium Americas Corp. (TSX: LAC) (NYSE: LAC). Lithium Americas owns the lithium reserves at Thacker Pass and will be
responsible for the processing and sale of the lithium produced. In January 2022, Lithium Americas provided an update on the
Thacker Pass project, which noted that final permitting decisions are expected to be received in the first quarter of 2022. Early-
works construction is expected to begin in 2022. At maturity, this management fee contract is expected to deliver fee income
similar to a mid-sized management fee coal mine.
56
Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
In 2022, capital expenditures are expected to be approximately $27 million primarily for the acquisition, relocation and
refurbishment of draglines, as well as the acquisition of other mining equipment to support the continued expansion of
contract-mining services beyond NAMining's historical dragline-oriented model, including the acquisition of equipment to
support the Thacker Pass lithium project. The cost of mining equipment related to Thacker Pass will be reimbursed by the
customer over a seven-year period from the equipment acquisition date.
Minerals Management Outlook
The Minerals Management segment derives income from royalty-based leases under which lessees make payments to the
Company based on their sale of natural gas, oil, natural gas liquids and coal, extracted primarily by third parties.
Operating profit and Segment adjusted EBITDA in 2022 are expected to decrease significantly from 2021 primarily driven by
an anticipated reduction in production due to the natural decline curve on wells in Ohio, expectations for natural gas and oil
prices, and the absence of $3.6 million of settlement income recognized in 2021. The Company expects oil and gas market
prices to moderate in 2022 and stabilize at levels consistent with averages over the second half of 2021.
Natural gas and oil benchmark prices increased during 2021 when compared with historical periods. If natural gas and oil
prices remain at higher levels than currently anticipated, results for the 2022 full year could be favorably impacted.
Commodity prices are inherently volatile and as an owner of royalty and mineral interests, the Company’s access to
information concerning activity and operations of its interests is limited. The Company's expectations are based on the best
information currently available and could vary as a result of adjustments made by operators and/or changes to commodity
prices.
The Company is in a period of transition where production from more recently acquired mineral interests is expected to begin
to offset anticipated declines in production at legacy natural gas wells. This transition is expected to occur over the next few
years as the Company’s portfolio of recently acquired mineral interests continues to expand. Minerals Management is
targeting additional investments in mineral and royalty interests of approximately $10 million in 2022. These investments are
expected to be accretive, but each investment's contribution to earnings is dependent on the details of that investment,
including the size and type of interests acquired and the stage and timing of mineral development. The contribution of each
investment could also vary due to commodity price changes. These acquired interests are expected to align with the
Company’s strategy of selectively acquiring mineral and royalty interests with a balance of near-term cash-flow yields and
long-term growth potential, in high-quality reservoirs offering diversification from the Company’s legacy mineral interests.
Consolidated Outlook
Overall, in 2022, NACCO expects consolidated net income and Consolidated Adjusted EBITDA to decrease significantly
from 2021. Lower operating profit in the Coal Mining segment and an anticipated reduction in income in the Minerals
Management segment are expected to be partially offset by higher operating profit at NAMining and lower income tax
expense. Additionally, the Company expects to recognize the value of the North Dakota office building and the membership
units in Midwest AgEnergy, which are expected to be received as part of the compensation from GRE upon the closing of the
transaction with Rainbow Energy. Securing contracts for new mining projects and acquisitions of additional mineral interests
could be accretive to the current forecast.
Consolidated capital expenditures are expected to be approximately $68 million in 2022. Capital expenditures in 2022 include
approximately $9 million for expenditures at Mitigation Resources of North America®. As a result of the forecasted capital
expenditures and anticipated decrease in net income, cash flow before financing activities is expected to return to a significant
use of cash in 2022.
Growth and Diversification
The Company is pursuing growth and diversification by strategically leveraging its core mining and natural resources
management skills to build a strong portfolio of affiliated businesses. Management continues to be optimistic about the long-
term outlook for growth in the NAMining and Minerals Management segments and in the Company's Mitigation Resources
57
Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
business. Each of these businesses continues to expand its pipeline of potential new projects with opportunities for growth and
diversification.
NAMining is pursuing growth and diversification by expanding the scope of its business development activities to include
potential customers who require a broad range of minerals and materials and by leveraging the Company’s core mining skills
to expand the range of contract mining services it provides. NAMining advanced these efforts in 2021 when it entered into a
contract to mine sand and gravel in Indiana and signed contracts to perform all mining operations at two sand and gravel
quarries located in Texas and Arkansas. The new contracts in Texas and Arkansas include responsibility for all mining
activities, including pre-strip, blasting, excavation and load and haul operations. These new contracts with leading suppliers of
construction materials in North America expand the range of contract mining services beyond the traditional scope of
NAMining's core, dragline-oriented limestone mining business and expand its geographic footprint beyond Florida. In
addition, NAMining continues to pursue additional opportunities to provide comprehensive mining services to operate entire
mines, as it expects to do at the new lithium project in Nevada. The goal is to build NAMining into a leading provider of
contract mining services for customers that produce a wide variety of minerals and materials. The Company believes
NAMining can grow to be a substantial contributor to operating profit, delivering unlevered after-tax returns on invested
capital in the mid-teens as this business model matures and achieves significant scale, but the pace of growth will be
dependent on the mix and scale of new projects.
The Minerals Management segment continues to grow and diversify by pursuing acquisitions of mineral and royalty interests
in the United States, in a market environment that the Company believes remains well-aligned with its strategy and objectives.
The Minerals Management segment will benefit from the continued development of its mineral properties without additional
capital investment, as all further development costs are borne entirely by third-party producers who lease the minerals. This
business model can deliver higher average operating margins over the life of a reserve than traditional oil and gas companies
that bear the cost of exploration, production and/or development. Catapult, the Company’s business unit focused on managing
and expanding the Company’s portfolio of oil and gas mineral and royalty interests, has developed a strong network to source
and secure new acquisitions, and has several potential acquisitions under review. The goal is to construct a diversified
portfolio of high-quality oil and gas mineral and royalty interests in the United States that deliver near-term cash flow yields
and long-term projected growth. The Company believes this business will provide unlevered after-tax returns on invested
capital in the low-to-mid-teens as the portfolio of reserves and mineral interests grows and this business model matures.
Mitigation Resources continues to expand its business, which creates and sells stream and wetland mitigation credits and
provides services to those engaged in permittee-responsible mitigation. This business offers an opportunity for growth and
diversification in an industry where the Company has substantial knowledge and expertise and a strong reputation. The
Mitigation Resources business has achieved several early successes and is positioned for additional growth. The Company's
goal is to grow Mitigation Resources into one of the ten largest U.S. providers of mitigation solutions, largely focused on
streams and wetlands, initially in the southeast United States. While this business is in the early stages of development, it is
currently focused on expanding and has established mitigation projects in Alabama, Mississippi, Texas and Tennessee. The
Company believes that Mitigation Resources can provide solid rates of return as this business matures.
The Company also continues to pursue activities which can strengthen the resiliency of its existing coal mining operations.
The Company remains focused on managing coal production costs and maximizing efficiencies and operating capacity at mine
locations to help customers with management fee contracts be more competitive. These activities benefit both customers and
the Company's Coal Mining segment, as fuel cost is a significant driver for power plant dispatch. Increased power plant
dispatch results in increased demand for coal by the Coal Mining segment's customers. Fluctuating natural gas prices and
availability of renewable energy sources, such as wind and solar, could affect the amount of electricity dispatched from coal-
fired power plants.
The Company continues to look for opportunities to expand its coal mining business where it can apply its management fee
business model to assume operation of existing surface coal mining operations in the United States. However, opportunities
are very limited in the current environment. In addition, the political and regulatory environment is not receptive to
development of new coal-fired power generation projects which would create opportunities to build and operate new coal
mines.
58
Item 7. MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF
OPERATIONS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
The Company is committed to maintaining a conservative capital structure as it continues to grow and diversify, while
avoiding unnecessary risk. Strategic diversification will generate cash that can be re-invested to strengthen and expand the
businesses. The Company also continues to maintain the highest levels of customer service and operational excellence with an
unwavering focus on safety and environmental stewardship.
RECENTLY ISSUED ACCOUNTING STANDARDS
See Note 2 to the Consolidated Financial Statements in this Form 10-K for a description of recently issued accounting
standards, if any, including actual and expected dates of adoption and effects to the Company's Consolidated Financial
Statements.
FORWARD-LOOKING STATEMENTS
The statements contained in “Management’s Discussion and Analysis of Financial Condition and Results of Operations” and
elsewhere throughout this Annual Report on Form 10-K that are not historical facts are “forward-looking statements” within
the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. These
forward-looking statements are made subject to certain risks and uncertainties, which could cause actual results to differ
materially from those presented. Readers are cautioned not to place undue reliance on these forward-looking statements,
which speak only as of the date hereof. The Company undertakes no obligation to publicly revise these forward-looking
statements to reflect events or circumstances that arise after the date hereof. Among the factors that could cause plans, actions
and results to differ materially from current expectations are, without limitation: (1) changes to or termination of customer or
other third-party contracts, or a customer or other third party default under a contract, (2) Any customer's premature facility
closure, including GRE’s failure to complete the sale of Coal Creek Station to Rainbow Energy, (3) a significant reduction in
purchases by the Company's customers, including as a result of changes in coal consumption patterns of U.S. electric power
generators, or changes in the power industry that would affect demand for the Company's coal and other mineral reserves, (4)
failure to obtain adequate insurance coverages at reasonable rates, (5) the impact of the COVID-19 pandemic, including any
impact on suppliers, customers and employees, (6) supply chain disruptions, including price increases and shortages of parts
and materials, (7) changes in tax laws or regulatory requirements, including the elimination of, or reduction in, the percentage
depletion tax deduction, changes in mining or power plant emission regulations and health, safety or environmental legislation,
(8) the ability of the Company to access credit in the current economic environment, or obtain financing at reasonable rates, or
at all, and to maintain surety bonds for mine reclamation as a result of current market sentiment for fossil fuels, (9) the effects
of investors’ and other stakeholders’ increasing attention to environmental, social and governance (“ESG”) matters, (10)
changes in costs related to geological and geotechnical conditions, repairs and maintenance, new equipment and replacement
parts, fuel or other similar items, (11) regulatory actions, changes in mining permit requirements or delays in obtaining mining
permits that could affect deliveries to customers, (12) weather conditions, extended power plant outages, liquidity events or
other events that would change the level of customers' coal or aggregates requirements, (13) weather or equipment problems
that could affect deliveries to customers, (14) failure or delays by the Company's lessees in achieving expected production of
natural gas and other hydrocarbons; the availability and cost of transportation and processing services in the areas where the
Company's oil and gas reserves are located; federal and state legislative and regulatory initiatives relating to hydraulic
fracturing; and the ability of lessees to obtain capital or financing needed for well-development operations and leasing and
development of oil and gas reserves on federal lands, (15) changes in the costs to reclaim mining areas, (16) costs to pursue
and develop new mining, mitigation and oil and gas opportunities and other value-added service opportunities, (17) delays or
reductions in coal or aggregates deliveries, (18) changes in the prices of hydrocarbons, particularly diesel fuel, natural gas and
oil, (19) the ability to successfully evaluate investments and achieve intended financial results in new business and growth
initiatives, (20) disruptions from natural or human causes, including severe weather, accidents, fires, earthquakes and terrorist
acts, any of which could result in suspension of operations or harm to people or the environment, and (21) the ability to attract,
retain, and replace workforce and administrative employees.
59
Item 7A. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
As a “smaller reporting company” as defined by Rule 12b-2 of the Securities Exchange Act of 1934, the Company is not
required to provide this information.
Item 8. FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
The information required by this Item 8 is set forth in the Financial Statements and Supplementary Data contained in Part IV
of this Form 10-K and is hereby incorporated herein by reference to such information.
Item 9. CHANGES IN AND DISAGREEMENTS WITH ACCOUNTANTS ON ACCOUNTING AND FINANCIAL
DISCLOSURE
There were no disagreements with accountants on accounting and financial disclosure for the two-year period ended
December 31, 2021 that require disclosure pursuant to this Item 9.
Item 9A. CONTROLS AND PROCEDURES
Evaluation of disclosure controls and procedures: An evaluation was carried out under the supervision and with the
participation of the Company's management, including the principal executive officer and the principal financial officer, of the
effectiveness of the Company's disclosure controls and procedures as of the end of the period covered by this report. Based on
that evaluation, these officers have concluded that the Company's disclosure controls and procedures are effective.
Management's report on internal control over financial reporting: Management is responsible for establishing and
maintaining adequate internal control over financial reporting. Under the supervision and with the participation of
management, including the principal executive officer and principal financial officer, the Company conducted an evaluation of
the effectiveness of internal control over financial reporting based on the framework in Internal Control — Integrated
Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission (2013 framework). Based on
this evaluation under the framework, management concluded that the Company's internal control over financial reporting was
effective as of December 31, 2021. The Company's effectiveness of internal control over financial reporting as of
December 31, 2021 has been audited by Ernst & Young LLP, an independent registered public accounting firm, as stated in its
report, which is included in Item 15 of this Form 10-K and incorporated herein by reference.
Changes in internal control: There have been no changes in the Company's internal control over financial reporting, that
occurred during the fourth quarter of 2021, that have materially affected, or are reasonably likely to materially affect, the
Company's internal control over financial reporting.
Item 9B. OTHER INFORMATION
None.
Item 9C. DISCLOSURE REGARDING FOREIGN JURISDICTIONS THAT PREVENT INSPECTIONS
None.
60
PART III
Item 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
Information with respect to Directors of the Company will be set forth in the 2022 Proxy Statement under the subheadings “Part
III — Proposals To Be Voted On At The 2022 Annual Meeting — Proposal 1 — Election of Directors,” which information is
incorporated herein by reference.
Information with respect to the audit review committee and the audit review committee financial expert will be set forth in the
2022 Proxy Statement under the subheading “Part I — Corporate Governance Information — Directors' Meetings and
Committees,” which information is incorporated herein by reference.
Information with respect to compliance with Section 16(a) of the Securities Exchange Act of 1934 by the Company's Directors,
executive officers and holders of more than ten percent of the Company's equity securities will be set forth in the 2022 Proxy
Statement under the subheading “Part IV — Other Important Information — Delinquent Section 16(a) Reports,” which
information is incorporated herein by reference.
The Company has adopted a code of business conduct and ethics applicable to all Company personnel, including the principal
executive officer, principal financial officer, principal accounting officer or controller, or other persons performing similar
functions. The code of business conduct and ethics, entitled the “Code of Corporate Conduct,” is posted on the Company's
website at www.nacco.com under “Corporate Governance.” If the Company makes any amendments to or grants any waivers
from the code of business conduct and ethics which are required to be disclosed pursuant to the Securities and Exchange Act of
1934, the Company will make such disclosure on the NACCO website.
Item 11. EXECUTIVE COMPENSATION
Information with respect to executive compensation will be set forth in the 2022 Proxy Statement under the headings “Part II —
Executive Compensation Information” and “Part III — Proposals To Be Voted On At The 2022 Annual Meeting — Proposal 1
— Election of Directors,” which information is incorporated herein by reference.
Item 12. SECURITY OWNERSHIP OF CERTAIN BENEFICIAL OWNERS AND MANAGEMENT AND RELATED
STOCKHOLDER MATTERS
Information with respect to security ownership of certain beneficial owners and management will be set forth in the 2022 Proxy
Statement under the subheading “Part IV — Other Important Information — Beneficial Ownership of Class A Common and
Class B Common,” which information is incorporated herein by reference.
Information with respect to compensation plans (including individual compensation arrangements) under which equity
securities are authorized for issuance will be set forth in the 2022 Proxy Statement under the subheading “Part IV — Other
Important Information — Equity Compensation Plan Information," which information is incorporated herein by reference.
Item 13. CERTAIN RELATIONSHIPS AND RELATED TRANSACTIONS, AND DIRECTOR INDEPENDENCE
Information with respect to certain relationships and related transactions will be set forth in the 2022 Proxy Statement under the
subheadings “Part I — Corporate Governance Information — Review and Approval of Related-Person Transactions,” which
information is incorporated herein by reference.
Item 14. PRINCIPAL ACCOUNTANT FEES AND SERVICES
Information with respect to principal accountant fees and services will be set forth in the 2022 Proxy Statement under the
heading “Part III — Proposals To Be Voted On At The 2022 Annual Meeting — Proposal 3 — Ratification of the Appointment
of Company's Independent Registered Public Accounting Firm,” which information is incorporated herein by reference.
61
Item 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
PART IV
(a) (1) and (2) The response to Item 15(a)(1) and (2) is set forth beginning at page F-1 of this Form 10-K.
(b) Financial Statement Schedules — The response to Item 15(c) is set forth beginning at page F-42 of this Form 10-K.
(c) Exhibits required by Item 601 of Regulation S-K
Exhibit
Number
Exhibit Description
(3) Articles of Incorporation and By-laws.
3.1(i)
3.1(ii)
Restated Certificate of Incorporation of the Company is incorporated herein by reference to Exhibit 3(i) to the
Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 1992, Commission File Number
1-9172.
Amended and Restated By-laws of the Company are incorporated herein by reference to Exhibit 3.1 to the
Company’s Current Report on Form 8-K, filed by the Company on December 18, 2014, Commission File Number
1-9172.
(4) Instruments defining the rights of security holders, including indentures.
4.1
4.2
4.3
4.4
4.5
4.6
4.7
4.8
The Company by this filing agrees, upon request, to file with the Securities and Exchange Commission the
instruments defining the rights of holders of long-term debt of the Company and its subsidiaries where the total
amount of securities authorized thereunder does not exceed 10% of the total assets of the Company and its
subsidiaries on a consolidated basis.
The Mortgage and Security Agreement, dated April 8, 1976, between The Falkirk Mining Company (as
Mortgagor) and Cooperative Power Association and United Power Association (collectively, as Mortgagee) is
incorporated herein by reference to Exhibit 4(ii) to the Company’s Annual Report on Form 10-K for the fiscal year
ended December 31, 1992, Commission File Number 1-9172.
Amendment No. 1 to the Mortgage and Security Agreement, dated as of December 15, 1993, between Falkirk
Mining Company (as Mortgagor) and Cooperative Power Association and United Power Association (collectively,
as Mortgagee) is incorporated herein by reference to Exhibit 4(iii) to the Company’s Annual Report on Form 10-K
for the fiscal year ended December 31, 1997, Commission File Number 1-9172.
Amended and Restated Stockholders' Agreement, dated as of September 29, 2017, among NACCO Industries, Inc.,
the other signatories thereto and NACCO Industries, Inc., as depository, is incorporated by reference to Exhibit
10.4 to the Company's Current Report on Form 8-K, filed by the Company on October 5, 2017, Commission File
Number 1-9172.
Amendment to Amended and Restated Stockholders' Agreement, dated as of February 14, 2019, among NACCO
Industries, Inc., the other signatories thereto and NACCO Industries, Inc., as depository, is incorporated by
reference to Exhibit 4.5 to the Company's Annual Report on Form 10-K for the fiscal year ended December 31,
2018, Commission File Number 1-9172.
Second Amendment to Amended and Restated Stockholders' Agreement, dated as of February 12, 2021, by and
among the Depository, NACCO Industries, Inc., the new Participating Stockholders identified on the signature
pages thereto and the Participating Stockholders under the Amended and Restated Stockholders' Agreement, dated
as of September 29, 2017, as amended, is incorporated by reference to Exhibit 60 of the Company's General
statement of acquisition of beneficial ownership on Form SC 13D, filed on February 12, 2021, Commission File
Number 1-9172.
Third Amendment to Amended and Restated Stockholders' Agreement, dated as of February 11, 2022, by and
among the Depository, NACCO Industries, Inc., the new Participating Stockholders identified on the signature
pages thereto and the Participating Stockholders under the Amended and Restated Stockholders' Agreement, dated
as of September 29, 2017, as amended, is incorporated by reference to Exhibit 99.8 of the Company's General
statement of acquisition of beneficial ownership on Form SC 13D, filed on February 11, 2022, Commission File
Number 1-9172.
Description of Securities is incorporated herein by reference to Exhibit 4.6 to the Company's Annual Report on
Form 10-K for the fiscal year ended December 31, 2019, Commission File Number 1-9172.
62
Exhibit
Number
Exhibit Description
(10) Material contracts
10.1*
NACCO Industries, Inc. Supplemental Executive Long-Term Incentive Bonus Plan (Amended and Restated March
1, 2012) is incorporated herein by reference to Appendix B to NACCO's Definitive Proxy Statement, filed by
NACCO on March 16, 2012, Commission File Number 1-9172.
10.2*
10.3*
10.4*
10.5*
10.6*
10.7*
10.8*
10.9
10.10
10.11
10.12
10.13
10.14*
10.15*
10.16*
10.17*
NACCO Industries, Inc. Executive Long-Term Incentive Compensation Plan (Amended and Restated March 1,
2019) is incorporated herein by reference to Exhibit 10.2 to the Company's Current Report on Form 8-K, filed by
the Company on May 8, 2019, Commission File Number 1-9172.
NACCO Industries, Inc. Executive Long-Term Incentive Compensation Plan (Amended and Restated March 1,
2021) is incorporated herein by reference to Exhibit 10.1 to the Company's Current Report on Form 8-K, filed by
the Company on May 19, 2021, Commission File Number 1-9172.
NACCO Industries, Inc. Non-Employee Directors' Equity Compensation Plan (Amended and Restated May 8,
2019) is incorporated herein by reference to Exhibit 10.1 to the Company's Current Report on Form 8-K, filed by
the Company on May 8, 2019, Commission File Number 1-9172.
NACCO Industries, Inc. Non-Employee Directors' Equity Compensation Plan (Amended and Restated May 19,
2021) is incorporated herein by reference to Exhibit 10.2 to the Company's Current Report on Form 8-K, filed by
the Company on May 19, 2021, Commission File Number 1-9172.
Form of Award Agreement for the NACCO Industries, Inc. Supplemental Executive Long-Term Incentive Bonus
Plan is incorporated by reference to Exhibit 10.8 to the Company's Current Report on Form 8-K, filed by the
Company on September 17, 2012, Commission File Number 1-9172.
Form of Cashless Exercise Award Agreement for the NACCO Industries, Inc. Executive Long-Term Incentive
Compensation Plan is incorporated herein by reference to Exhibit 10.9 to the Company's Annual Report on Form
10-K for the fiscal year ended December 31, 2019, Commission File Number 1-9172.
Form of Non-Cashless Exercise Award Agreement for the NACCO Industries, Inc. Executive Long-Term
Incentive Compensation Plan is incorporated herein by reference to Exhibit 10.10 to the Company's Annual Report
on Form 10-K for the fiscal year ended December 31, 2019, Commission File Number 1-9172.
Separation Agreement, dated as of September 29, 2017, between NACCO Industries, Inc. and Hamilton Beach
Brands Holding Company, is incorporated by reference to Exhibit 10.1 of Hamilton Beach Brands Holding
Company's Current Report on Form 8-K, filed on October 4, 2017, Commission File Number 1-9172.
Tax Allocation Agreement, dated as of September 29, 2017, between NACCO Industries, Inc. and Hamilton Beach
Brands Holding Company, is incorporated by reference to Exhibit 10.3 of Hamilton Beach Brands Holding
Company's Current Report on Form 8-K, filed on October 4, 2017, Commission File Number 1-9172.
Consulting Agreement, dated as of September 29, 2017, between NACCO Industries, Inc. and Alfred M. Rankin,
Jr., is incorporated by reference to Exhibit 10.5 of NACCO Industries, Inc.'s Current Report on Form 8-K, filed on
October 5, 2017, Commission File Number 1-9172.
Amendment to Consulting Agreement, dated as of December 15, 2020, between NACCO Industries, Inc. and
Alfred M. Rankin, Jr., is incorporated by reference to Exhibit 10.1 of NACCO Industries, Inc.'s Current Report on
Form 8-K, filed on December 15, 2020, Commission File Number 1-9172.
Amendment to Consulting Agreement, dated as of December 21, 2021, between NACCO Industries, Inc. and
Alfred M. Rankin, Jr., is incorporated by reference to Exhibit 10.1 of NACCO Industries, Inc.'s Current Report on
Form 8-K, filed on December 22, 2021, Commission File Number 1-9172.
NACCO Industries, Inc. Short-Term Incentive Compensation Plan (Effective as of March 1, 2019) is incorporated
herein by reference to Exhibit 10.1 to the Company's Current Report on Form 8-K, filed by the Company on
February 13, 2019, Commission File Number 1-9172.
The North American Coal Corporation Supplemental Retirement Benefit Plan (Amended and Restated as of
January 1, 2008) is incorporated herein by reference to Exhibit 10.12 to the Company’s Current Report on Form 8-
K, filed by the Company on December 19, 2007, Commission File Number 1-9172.
Amendment No. 1 to The North America Coal Corporation Supplemental Retirement Benefit Plan (Amended and
Restated as of January 1, 2008) is incorporated herein by reference to Exhibit 10.41 to the Company's Annual
Report on Form 10-K for the fiscal year ended December 31, 2009, Commission File Number 1-9172.
The North American Coal Corporation Annual Incentive Compensation Plan (Amended and Restated Effective
March 1, 2015) is incorporated herein by reference to Exhibit 10.3 to the Company’s Current Report on Form 8-K,
filed by the Company on May 18, 2015, Commission File Number 1-9172.
63
Exhibit
Number
10.18*
10.19
10.20
10.21
10.22
10.23
10.24
10.25
10.26
10.27
10.28
Exhibit Description
Amendment No. 2 to The North American Coal Corporation Supplemental Retirement Benefit Plan (Amended and
Restated as of January 1, 2008) is incorporated herein by reference to Exhibit 10.40 to the Company's Annual
Report on Form 10-K for the fiscal year ended December 31, 2010, Commission File Number 1-9172.
Coteau Lignite Sales Agreement by and between The Coteau Properties Company and Dakota Coal Company,
dated as of January 1, 1990, is incorporated herein by reference to Exhibit 10.11 to the Company’s Quarterly
Report on Form 10-Q/A, filed by the Company on March 20, 2013, Commission File Number 1-9172.+
First Amendment to Coteau Lignite Sales Agreement by and between The Coteau Properties Company and Dakota
Coal Company, dated as of June 1, 1994, is incorporated herein by reference to Exhibit 10.12 to the Company’s
Quarterly Report on Form 10-Q/A, filed by the Company on March 20, 2013, Commission File Number 1-9172.+
Second Amendment to Coteau Lignite Sales Agreement by and between The Coteau Properties Company and
Dakota Coal Company, dated as of January 1, 1997, is incorporated herein by reference to Exhibit 10.13 to the
Company’s Quarterly Report on Form 10-Q/A, filed by the Company on March 20, 2013, Commission File
Number 1-9172.+
Option and Put Agreement by and among The North American Coal Corporation, Dakota Coal Company and the
State of North Dakota, dated as of January 1, 1990, is incorporated herein by reference to Exhibit 10.14 to the
Company’s Quarterly Report on Form 10-Q/A, filed by the Company on March 20, 2013, Commission File
Number 1-9172.
First Amendment to the Option and Put Agreement by and among The North American Coal Corporation, Dakota
Coal Company and the State of North Dakota, dated as of June 1, 1994, is incorporated herein by reference to
Exhibit 10.15 to the Company’s Quarterly Report on Form 10-Q/A, filed by the Company on March 20, 2013,
Commission File Number 1-9172.
Lignite Sales Agreement by and between Mississippi Lignite Mining Company and Choctaw Generation Limited
Partnership, dated as of April 1, 1998, is incorporated herein by reference to Exhibit 10.16 to the Company’s
Quarterly Report on Form 10-Q/A, filed by the Company on March 20, 2013, Commission File Number 1-9172.+
First Amendment to Lignite Sales Agreement by and between Mississippi Lignite Mining Company and Choctaw
Generation Limited Partnership, dated as of August 30, 2016, is incorporated herein by reference to Exhibit 10.1 to
the Company’s Quarterly Report on Form 10-Q, filed by the Company on November 1, 2016, Commission File
Number 1-9172.+
Pay Scale Agreement by and between Mississippi Lignite Mining Company and Choctaw Generation Limited
Partnership, dated as of September 29, 2005, is incorporated herein by reference to Exhibit 10.17 to the Company’s
Quarterly Report on Form 10-Q/A, filed by the Company on March 20, 2013, Commission File Number 1-9172.
Consent and Agreement by and among Mississippi Lignite Mining Company, Choctaw Generation Limited
Partnership, SE Choctaw L.L.C. and Citibank, N.A., dated as of December 20, 2002, is incorporated herein by
reference to Exhibit 10.29 to the Company’s Quarterly Report on Form 10-Q/A, filed by the Company on March
20, 2013, Commission File Number 1-9172.
Amendment No. 1 to Lignite Sales Agreement, Settlement Agreement and Release by and between Mississippi
Lignite Mining Company and Choctaw Generation Limited Partnership, LLLP, dated as of November 16, 2018, is
incorporated herein by reference to Exhibit 10.33 to the Company's Annual Report on Form 10-K for the fiscal
year ended December 31, 2018, Commission File Number 1-9172.
10.29** Amendment No. 2 to Lignite Sales Agreement, Settlement Agreement and Release by and between Mississippi
Lignite Mining Company and Choctaw Generation Limited Partnership, LLLP, dated as of November 24, 2021.
10.30
10.31
10.32
10.33
Second Restatement of Coal Sales Agreement by and between The Falkirk Mining Company and Great River
Energy, dated as of January 1, 2007, is incorporated herein by reference to Exhibit 10.18 to the Company’s
Quarterly Report on Form 10-Q/A, filed by the Company on March 20, 2013, Commission File Number 1-9172.+
Amendment No. 1 to Second Restatement of Coal Sales Agreement, by and between The Falkirk Mining Company
and Great River Energy, dated as of January 21, 2011, is incorporated herein by reference to Exhibit 10.19 to the
Company’s Quarterly Report on Form 10-Q/A, filed by the Company on March 20, 2013, Commission File
Number 1-9172.
Amendment No. 2 to Second Restatement of Coal Sales Agreement, by and between The Falkirk Mining Company
and Great River Energy, dated as of March 1, 2014, is incorporated herein by reference to Exhibit 10.52 to the
Company's Annual Report on Form 10-K for the fiscal year ended December 31, 2013, Commission File Number
1-9172.
Amendment No. 3 to Second Restatement of Coal Sales Agreement, by and between The Falkirk Mining Company
and Great River Energy, dated as of January 1, 2019, is incorporated herein by reference to Exhibit 10.37 to the
Company's Annual Report on Form 10-K for the fiscal year ended December 31, 2018, Commission File Number
1-9172.
64
Exhibit
Number
10.34
10.35
Exhibit Description
Restatement of Option Agreement by and among The Falkirk Mining Company, Cooperative Power Association,
United Power Association, and the State of North Dakota, dated as of January 1, 1997, is incorporated herein by
reference to Exhibit 10.20 to the Company’s Quarterly Report on Form 10-Q/A, filed by the Company on March
20, 2013, Commission File Number 1-9172.
Termination Agreement and Release, by and among The Falkirk Mining Company, Great River Energy and NoDak
Energy Investments Corporation, dated June 30, 2021, is incorporated herein by reference to Exhibit 10.6 to the
Company's Quarterly Report on Form 10-Q, filed by the Company on August 4, 2021, Commission File Number
1-9172.
10.36** Amendment No. 1 to Termination Agreement and Release, by and between The Falkirk Mining Company, NoDak
10.37
***
10.38
***
10.39
***
10.40
10.41
10.42
10.43
10.44
10.45
10.46
10.47
10.48
10.49
Energy Investments Corporation and Great River Energy, dated as of December 28, 2021.
Coal Sales Agreement, by and between The Falkirk Mining Company and Rainbow Energy Center, LLC, dated
June 30, 2021, is incorporated herein by reference to Exhibit 10.1 to the Company's Quarterly Report on Form 10-
Q, filed by the Company on August 4, 2021, Commission File Number 1-9172.
Guaranty by REMC Assets, LP, dated June 17, 2021, is incorporated herein by reference to Exhibit 10.2 to the
Company's Quarterly Report on Form 10-Q, filed by the Company on August 4, 2021, Commission File Number
1-9172.
Mortgage, Assignment of Leases, Rents and As-Extracted Collateral, Security Agreement, Financing Statement
and Fixture Filing, by and between The Falkirk Mining Company and Rainbow Energy Center, LLC, dated June
30, 2021, is incorporated herein by reference to Exhibit 10.3 to the Company's Quarterly Report on Form 10-Q,
filed by the Company on August 4, 2021, Commission File Number 1-9172.
Security Agreement, by and between The Falkirk Mining Company and Rainbow Energy Center, LLC, dated June
30, 2021, is incorporated herein by reference to Exhibit 10.4 to the Company's Quarterly Report on Form 10-Q,
filed by the Company on August 4, 2021, Commission File Number 1-9172.
Option Agreement, by and between The Falkirk Mining Company, Rainbow Energy Center, LLC and the State of
North Dakota, Doing Business as The Bank of North Dakota, dated June 30, 2021, is incorporated herein by
reference to Exhibit 10.5 to the Company's Quarterly Report on Form 10-Q, filed by the Company on August 4,
2021, Commission File Number 1-9172.
Third Restatement of Lignite Mining Agreement by and between The Sabine Mining Company and Southwestern
Electric Power Company, dated as of January 1, 2008, is incorporated herein by reference to Exhibit 10.21 to the
Company’s Quarterly Report on Form 10-Q/A, filed by the Company on March 20, 2013, Commission File
Number 1-9172.+
Amendment No. 1 to Third Restatement of Lignite Mining Agreement by and between The Sabine Mining
Company and Southwestern Electric Power Company, dated as of October 18, 2013 is incorporated herein by
reference to Exhibit 10.43 to the Company's Annual Report on Form 10-K for the fiscal year ended December 31,
2014, Commission File Number 1-9172.
Option Agreement by and among The North American Coal Corporation, Southwestern Electric Power Company
and Longview National Bank, dated as of January 15, 1981, is incorporated herein by reference to Exhibit 10.22 to
the Company’s Quarterly Report on Form 10-Q/A, filed by the Company on March 20, 2013, Commission File
Number 1-9172.
Addendum to Option Agreement, by and among The North American Coal Corporation, Southwestern Electric
Power Company and Longview National Bank, dated as of January 15, 1981 is incorporated herein by reference to
Exhibit 10.23 to the Company’s Quarterly Report on Form 10-Q/A, filed by the Company on March 20, 2013,
Commission File Number 1-9172.
Amendment to Option Agreement, by and among The North American Coal Corporation, Southwestern Electric
Power Company and Longview National Bank, dated as of December 2, 1996, is incorporated herein by reference
to Exhibit 10.24 to the Company’s Quarterly Report on Form 10-Q/A, filed by the Company on March 20, 2013,
Commission File Number 1-9172.
Second Amendment to Option Agreement, by and among The North American Coal Corporation, Southwestern
Electric Power Company and Regions Bank, dated as of January 1, 2008, is incorporated herein by reference to
Exhibit 10.25 to the Company’s Quarterly Report on Form 10-Q/A, filed by the Company on March 20, 2013,
Commission File Number 1-9172.
Agreement by and among The North American Coal Corporation, Southwestern Electric Power Company, Texas
Commerce Bank-Longview, Nortex Mining Company and The Sabine Mining Company, dated as of June 30,
1988, is incorporated herein by reference to Exhibit 10.26 to the Company’s Quarterly Report on Form 10-Q/A,
filed by the Company on March 20, 2013, Commission File Number 1-9172.
Lignite Sales Agreement between Coyote Creek Mining Company, L.L.C. and Otter Tail Power Company,
Northern Municipal Power Agency, Montana-Dakota Utilities Co. and Northwestern Corporation dated as of
October 10, 2012 is incorporated herein by reference to Exhibit 10.58 to the Company’s Annual Report on Form
10-K, filed by the Company on March 6, 2013, Commission File Number 1-9172.++
65
Exhibit
Number
10.50
10.51
10.52*
10.53*
10.54*
10.55*
10.56
10.57
10.58
10.59
10.60
Exhibit Description
First Amendment to Lignite Sales Agreement, dated as of January 30, 2014, between Coyote Creek Mining
Company, L.L.C. and Otter Tail Power Company, Northern Municipal Power Agency, Montana-Dakota Utilities
Co., a division of MDU Resources Group, Inc. and NorthWestern Corporation is incorporated herein by reference
to Exhibit 10.1 to the Company’s Quarterly Report on Form 8-K, filed by the Company on January 30, 2014,
Commission File Number 1-9172.
Second Amendment to Lignite Sales Agreement, dated as of March 16, 2015, between Coyote Creek Mining
Company, L.L.C. and Otter Tail Power Company, Northern Municipal Power Agency, Montana-Dakota Utilities
Co., a division of MDU Resources Group, Inc., and NorthWestern Corporation is incorporated herein by reference
to Exhibit 10.1 to the Company’s Quarterly Report on Form 10-Q, filed by the Company on May 5, 2015,
Commission File Number 1-9172.
Amendment No. 3 to The North American Coal Corporation Supplemental Retirement Benefit Plan (Amended and
Restated as of January 1, 2008) is incorporated herein by reference to Exhibit 10.1 to the Company's Quarterly
Report on Form 10-Q, filed by the Company on October 30, 2013, Commission File Number 1-9172.
Amendment No. 4 to The North American Coal Corporation Supplemental Retirement Benefit Plan (Amended and
Restated as of January 1, 2008) is incorporated herein by reference to Exhibit 10.54 to the Company's Annual
Report on Form 10-K for the fiscal year ended December 31, 2014, Commission File Number 1-9172.
Amendment No. 5 to The North American Coal Corporation Supplemental Retirement Benefit Plan (Amended and
Restated as of January 1, 2008) is incorporated herein by reference to Exhibit 10.57 to the Company's Annual
Report on Form 10-K for the fiscal year ended December 31, 2015, Commission File Number I-9172.
Amendment No. 6 to The North American Coal Corporation Supplemental Retirement Benefit Plan (Amended and
Restated as of January 1, 2008) is incorporated herein by reference to Exhibit 10.52 to the Company's Annual
Report on Form 10-K for the fiscal year ended December 31, 2016, Commission File Number I-9172.
Agreement, dated as of March 16, 2015, among The North American Coal Corporation, Otter Tail Power
Company, Northern Municipal Power Agency, Montana-Dakota Utilities Co., a division of MDU Resources
Group, Inc. and Northwestern Corporation is incorporated herein by reference to Exhibit 10.2 to the Company's
Quarterly Report on Form 10-Q, filed by the Company on May 5, 2015, Commission File Number 1-9172.
The North American Coal Corporation Excess Retirement Plan (Amended and Restated Effective January 1, 2020)
is incorporated herein by reference to Exhibit 10.1 to the Company's Current Report on Form 8-K, filed by the
Company on December 18, 2019, Commission File Number 1-9172.
Amended and Restated Credit Agreement by and among The North American Coal Corporation and the Lenders
party thereto and KeyBank National Association as Syndication Agent, PNC Bank National Association as
Administrative Agent and KeyBanc Capital Markets Inc. and PNC Capital Markets LLC as Joint Lead Arrangers
and Joint Bookrunners, dated as of August 11, 2017 is incorporated herein by reference to Exhibit 10.1 to the
Company's Current Report on Form 8-K, filed by the Company on August 15, 2017, Commission File Number
1-9172.
Amended and Restated Credit Agreement by and among The North American Coal Corporation and the Guarantors
party thereto and the Lenders party thereto and KeyBank National Association as Syndication Agent, PNC Bank
National Association as Administrative Agent and KeyBanc Capital Markets Inc. and PNC Capital Markets LLC
as Joint Lead Arrangers and Joint Bookrunners, dated as of November 12, 2021 is incorporated herein by reference
to Exhibit 10.1 to the Company's Current Report on Form 8-K, filed by the Company on November 15, 2021,
Commission File Number 1-9172.
Revolving Credit Commitment Increase Agreement, dated as of December 10, 2021 is incorporated herein by
reference to Exhibit 10.1 to the Company's Current Report on Form 8-K, filed by the Company on December 13,
2021. Commission File Number 1-9172.
66
(21) Subsidiaries. A list of the subsidiaries of the Company is attached hereto as Exhibit 21.
(23) Consents of experts and counsel.
23.1
Consents of experts and counsel.
(24) Powers of Attorney.
24.1
24.2
24.3
24.4
24.5
24.6
24.7
24.8
24.9
24.10
24.11
A copy of a power of attorney for John S. Dalrymple is attached hereto as Exhibit 24.1.
A copy of a power of attorney for John P. Jumper is attached hereto as Exhibit 24.2.
A copy of a power of attorney for Dennis W. LaBarre is attached hereto as Exhibit 24.3.
A copy of a power of attorney for Michael S. Miller is attached hereto as Exhibit 24.4.
A copy of a power of attorney for Richard de J. Osborne is attached hereto as Exhibit 24.5.
A copy of a power of attorney for Alfred M. Rankin, Jr. is attached hereto as Exhibit 24.6.
A copy of a power of attorney for Matthew M. Rankin is attached hereto as Exhibit 24.7.
A copy of a power of attorney for Roger F. Rankin is attached hereto as Exhibit 24.8.
A copy of a power of attorney for Lori J. Robinson is attached hereto as Exhibit 24.9.
A copy of a power of attorney for Robert S. Shapard is attached hereto as Exhibit 24.10.
A copy of a power of attorney for Britton T. Taplin is attached hereto as Exhibit 24.11.
(31) Rule 13a-14(a)/15d-14(a) Certifications.
31(i)(1)
31(i)(2)
(32)
(95)
96.1**
96.2**
96.3**
96.4**
96.5**
(99.1**)
(99.2**)
Certification of J.C. Butler, Jr. pursuant to Rule 13a-14(a)/15d-14(a) of the Exchange Act is attached hereto as
Exhibit 31(i)(1).
Certification of Elizabeth I. Loveman pursuant to Rule 13a-14(a)/15d-14(a) of the Exchange Act is attached hereto
as Exhibit 31(i)(2).
Certifications pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act
of 2002, signed and dated by J.C. Butler, Jr. and Elizabeth I. Loveman.
Mine Safety Disclosure Exhibit is attached hereto as Exhibit 95.
Technical Report Summary relating to The Coteau Properties Company, dated December 31, 2021.
Technical Report Summary relating to the Coyote Creek Mining Company, LLC., dated December 31, 2021.
Technical Report Summary relating to The Falkirk Mining Company, dated December 31, 2021.
Technical Report Summary relating to the Mississippi Lignite Mining Company, dated December 31, 2021.
Supplemental Figures Attachment
Reserve Report of Catapult Mineral Partners.
Supplemental Figures Attachment
101.INS
Inline XBRL Instance Document
101.SCH Inline XBRL Taxonomy Extension Schema Document
101.CAL Inline XBRL Taxonomy Extension Calculation Linkbase Document
101.DEF Inline XBRL Taxonomy Extension Definition Linkbase Document
101.LAB Inline XBRL Taxonomy Extension Label Linkbase Document
101.PRE Inline XBRL Taxonomy Extension Presentation Linkbase Document
104
Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)
67
*
**
***
+
++
Management contract or compensation plan or arrangement required to be filed as an exhibit pursuant to Item15(b)
of this Annual Report on Form 10-K.
Filed herewith.
Certain confidential information contained in this agreement has been omitted because it (i) is not material and (ii)
would be competitively harmful if publicly disclosed.
Portions of Exhibit have been omitted and filed separately with the Securities and Exchange Commission in
reliance on Rule 24b-2 and an Order from the Commission granting the Company's request for confidential
treatment dated March 27, 2013. Portions for which confidential treatment has been granted have been marked
with three asterisks [***] and a footnote indicating "Confidential treatment requested".
Portions of Exhibit have been omitted and filed separately with the Securities and Exchange Commission in
reliance on Rule 24b-2 and an Order from the Commission granting the Company's request for confidential
treatment dated April 2, 2013. Portions for which confidential treatment has been granted have been marked with
three asterisks [***] and a footnote indicating "Confidential treatment requested".
68
Pursuant to the requirements of Section 13 or 15(d) of the Securities Exchange Act of 1934, the registrant has duly caused this
report to be signed on its behalf by the undersigned, thereunto duly authorized.
SIGNATURES
NACCO Industries, Inc.
By:
/s/ Elizabeth I. Loveman
Elizabeth I. Loveman
Vice President and Controller
(principal financial and accounting officer)
March 2, 2022
69
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/ J.C. Butler, Jr.
J.C. Butler, Jr.
/s/ Elizabeth I. Loveman
Elizabeth I. Loveman
*John S. Dalrymple
John S. Dalrymple
* John P. Jumper
John P. Jumper
* Dennis W. LaBarre
Dennis W. LaBarre
* Michael S. Miller
Michael S. Miller
* Richard de J. Osborne
Richard de J. Osborne
* Alfred M. Rankin, Jr.
Alfred M. Rankin, Jr.
* Matthew M. Rankin
Matthew M. Rankin
* Roger F. Rankin
Roger F. Rankin
*Lori J. Robinson
Lori J. Robinson
*Robert S. Shapard
Robert S. Shapard
* Britton T. Taplin
Britton T. Taplin
President and Chief Executive Officer (principal
executive officer)
March 2, 2022
Vice President and Controller (principal financial
and accounting officer)
March 2, 2022
Director
Director
Director
Director
Director
Director
Director
Director
Director
Director
Director
March 2, 2022
March 2, 2022
March 2, 2022
March 2, 2022
March 2, 2022
March 2, 2022
March 2, 2022
March 2, 2022
March 2, 2022
March 2, 2022
March 2, 2022
* Elizabeth I. Loveman, by signing her name hereto, does hereby sign this Form 10-K on behalf of each of the above named
and designated directors of the Company pursuant to a Power of Attorney executed by such persons and filed with the
Securities and Exchange Commission.
/s/ Elizabeth I. Loveman
Elizabeth I. Loveman, Attorney-in-Fact
March 2, 2022
70
ANNUAL REPORT ON FORM 10-K
ITEM 8, ITEM 15(a)(1) AND (2), AND ITEM 15(c)
FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
LIST OF FINANCIAL STATEMENTS AND FINANCIAL STATEMENT SCHEDULES
FINANCIAL STATEMENTS
FINANCIAL STATEMENT SCHEDULES
YEAR ENDED DECEMBER 31, 2021
NACCO INDUSTRIES, INC.
CLEVELAND, OHIO
F-1
FORM 10-K
ITEM 15(a)(1) AND (2)
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
LIST OF FINANCIAL STATEMENTS AND FINANCIAL STATEMENT SCHEDULES
The following consolidated financial statements of NACCO Industries, Inc. and Subsidiaries and the reports of the
Company's independent registered public accounting firm (PCAOB ID:42) are incorporated by reference in Item 8:
Report of Ernst & Young LLP, Independent Registered Public Accounting Firm — For each of the two years in the
period ended December 31, 2021.
Report of Ernst & Young LLP, Independent Registered Public Accounting Firm on Internal Control Over Financial
Reporting — As of December 31, 2021.
Consolidated Statements of Operations
Consolidated Statements of Comprehensive Income (Loss)
Consolidated Balance Sheets
Consolidated Statements of Cash Flows
Consolidated Statements of Equity
Notes to Consolidated Financial Statements
F-3
F-5
F-6
F-7
F-8
F-9
F-10
F-11
The following consolidated financial statement schedules of NACCO Industries, Inc. and Subsidiaries are included in
Item 15(c):
Schedule I — Condensed Financial Information of the Parent
Schedule II — Valuation and Qualifying Accounts
All other schedules for which provision is made in the applicable accounting regulation of the SEC are not required under
the related instructions or are inapplicable, and therefore have been omitted.
F-2
Report of Independent Registered Public Accounting Firm
To the Shareholders and the Board of Directors of NACCO Industries, Inc.
Opinion on the Financial Statements
We have audited the accompanying consolidated balance sheets of NACCO Industries, Inc. and Subsidiaries (the Company) as
of December 31, 2021 and 2020, the related consolidated statements of operations, comprehensive income (loss), equity and
cash flows for the years then ended, and the related notes and the financial statement schedules listed in the Index at Item 15(a)
(collectively referred to as the “consolidated financial statements”). In our opinion, the consolidated financial statements present
fairly, in all material respects, the financial position of the Company at December 31, 2021 and 2020, and the results of its
operations and its cash flows for the years then ended, in conformity with U.S. generally accepted accounting principles.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States)
(PCAOB), the Company's internal control over financial reporting as of December 31, 2021, based on criteria established in
Internal Control-Integrated Framework issued by the Committee of Sponsoring Organizations of the Treadway Commission
(2013 framework) and our report dated March 2, 2022 expressed an unqualified opinion thereon.
Basis for Opinion
These financial statements are the responsibility of the Company's management. Our responsibility is to express an opinion on
the Company’s financial statements based on our audits. We are a public accounting firm registered with the 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
audit to obtain reasonable assurance about whether the financial statements are free of material misstatement, whether due to
error or fraud. Our audits included performing procedures to assess the risks of material misstatement of the 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 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 financial statements. We believe that our audits provide a reasonable basis for our opinion.
Critical Audit Matter
The critical audit matter communicated below is a matter arising from the current period audit of the financial statements that
was communicated or required to be communicated to the audit review committee and that: (1) relates to accounts or
disclosures that are material to the 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 a separate opinion on
the critical audit matter or on the accounts or disclosures to which it relates.
F-3
Falkirk and Great River Energy Contract Termination
Description of
the Matter
As discussed in Note 1 to the consolidated financial statements, during June 2021, Great River
Energy (“GRE”) entered into an agreement to sell Coal Creek Station and the adjacent high-
voltage direct current transmission line to Bismarck, North Dakota-based Rainbow Energy
Center, LLC (“Rainbow Energy”) and its affiliates. The closing of the transaction between GRE
and Rainbow Energy is subject to the satisfaction of certain conditions.
Upon completion of the sale of Coal Creek Station, the existing Coal Sales Agreement, the
existing Mortgage and Security Agreement and the existing Option Agreement between GRE
and the Falkirk Mining Company (“Falkirk”), a wholly owned subsidiary of North American
Coal Corporation (“NACoal”), will terminate. If GRE’s efforts to sell the power plant are
successful, a new Coal Sales Agreement (“CSA”) between Falkirk and Rainbow Energy will
become effective and Falkirk will supply all coal requirements of Coal Creek Station concurrent
with Rainbow Energy’s acquisition of the power plant. The Company evaluated whether the
GRE announcement in June 2021 was a variable interest entity (“VIE)” reconsideration event
and concluded it was not.
Auditing the disclosure of the terms of the contract termination was especially complex in
determining whether the GRE contract termination and the subsequent agreement between
Falkirk and Rainbow Energy will result in a reconsideration event, a change in the conclusion
that Falkirk meets the definition of a VIE and the determination of the primary beneficiary of
the VIE. Evaluating the Company’s judgments in determining whether an entity is a VIE and
the primary beneficiary of the VIE requires a high degree of complex auditor judgment.
How We
Addressed the
Matter in Our
Audit
We obtained an understanding, evaluated and tested the design and operating effectiveness of
the controls surrounding the Company’s processes to assess the implications of significant
transactions and events that could trigger a VIE reconsideration event.
To test the implications of the transaction, our audit procedures included, among other things,
inspecting the termination agreement between Falkirk and GRE and new CSA between Falkirk
and Rainbow Energy that are both effective upon regulatory approval of the sale of Coal Creek
Station and evaluating the VIE assessment performed by the Company. We evaluated the
significant terms of the contracts and whether the June 2021 announcement by GRE or the
contract termination and subsequent agreement between Falkirk and Rainbow Energy will result
in a reconsideration event, a change in the conclusion that Falkirk meets the definition of a VIE
and the determination of the primary beneficiary.
/s/ Ernst & Young LLP
We have served as the Company’s auditor since 2002.
Cleveland, Ohio
March 2, 2022
F-4
Report of Independent Registered Public Accounting Firm
To the Stockholders and the Board of Directors of NACCO Industries, Inc.
Opinion on Internal Control Over Financial Reporting
We have audited NACCO Industries, Inc. and Subsidiaries’ internal control over financial reporting as of December 31, 20210,
based on criteria established in Internal Control—Integrated Framework issued by the Committee of Sponsoring Organizations
of the Treadway Commission (2013 framework) (the COSO criteria). In our opinion, NACCO Industries, Inc. and Subsidiaries
(the Company) maintained, in all material respects, effective internal control over financial reporting as of December 31, 2021,
based on the COSO criteria.
We also have audited, in accordance with the standards of the Public Company Accounting Oversight Board (United States)
(PCAOB), the 2021 consolidated financial statements of the Company and our report dated March 2, 2022 expressed an
unqualified opinion thereon.
Basis for Opinion
The Company’s management is responsible 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 in Item 9A. Our responsibility is to express an opinion on the Company’s internal
control over financial reporting based on our audit. We are a public accounting firm registered with the 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 audit in accordance with the standards of the PCAOB. Those standards require that we plan and perform the
audit to obtain reasonable assurance about whether effective internal control over financial reporting was maintained in all
material respects.
Our audit included obtaining an understanding of internal control over financial reporting, assessing the risk that a material
weakness exists, testing and evaluating the design and operating effectiveness of internal control based on the assessed risk, and
performing such other procedures as we considered necessary in the circumstances. We believe that our audit provides a
reasonable basis for our opinion.
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 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.
/s/ Ernst & Young LLP
Cleveland, Ohio
March 2, 2022
F-5
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
Year Ended December 31
2021
2020
(In thousands, except per share data)
$
191,846 $
148,394
43,452
60,843
10,333
55,722
3,556
(60)
—
59,218
55,410
1,719
(449)
1,297
(3,423)
(584)
(1,440)
56,850
8,725
128,432
111,463
16,969
60,203
—
53,062
2,572
(269)
8,359
63,724
13,448
1,354
(1,200)
1,641
(1,226)
(1,379)
(810)
14,258
(535)
$
$
$
48,125 $
14,793
6.73 $
6.69 $
7,146
7,190
2.11
2.10
7,026
7,057
Revenues
Cost of sales
Gross profit
Earnings of unconsolidated operations
Contract termination settlement
Operating expenses
Selling, general and administrative expenses
Amortization of intangible assets
Gain on sale of assets
Asset impairment charges
Operating profit
Other (income) expense
Interest expense
Interest income
Closed mine obligations
Gain on equity securities
Other, net
Income before income tax provision (benefit)
Income tax provision (benefit)
Net income
Earnings per share:
Basic earnings per share
Diluted earnings per share
Basic weighted average shares outstanding
Diluted weighted average shares outstanding
See notes to the Consolidated Financial Statements.
F-6
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
Net income
Other comprehensive income
Current period pension and postretirement plan adjustment, net of $864 tax expense and
$213 tax benefit in 2021 and 2020, respectively
Reclassification of pension and postretirement adjustments into earnings, net of $170
and $129 tax benefit in 2021 and 2020, respectively
Total other comprehensive income
Comprehensive income
See notes to the Consolidated Financial Statements.
Year Ended December 31
2021
2020
(In thousands)
$
48,125 $
14,793
2,851
572
3,423
(697)
435
(262)
$
51,548 $
14,531
F-7
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
ASSETS
Current assets
Cash and cash equivalents
Trade accounts receivable
Accounts receivable from affiliates
Inventories
Refundable federal income taxes
Prepaid insurance
Other current assets
Total current assets
Property, plant and equipment, net
Intangibles, net
Investment in unconsolidated subsidiaries
Operating lease right-of-use assets
Other non-current assets
Total assets
LIABILITIES AND EQUITY
Current liabilities
Accounts payable
Accounts payable to affiliates
Revolving credit agreements
Current maturities of long-term debt
Asset retirement obligations
Accrued payroll
Deferred revenue
Other current liabilities
Total current liabilities
Long-term debt
Operating lease liabilities
Asset retirement obligations
Pension and other postretirement obligations
Deferred income taxes
Liability for uncertain tax positions
Other long-term liabilities
Total liabilities
Stockholders’ equity
Common stock:
Class A, par value $1 per share, 5,616,568 shares outstanding (2020 - 5,489,615 shares outstanding)
Class B, par value $1 per share, convertible into Class A on a one-for-one basis, 1,566,613 shares
outstanding (2020 - 1,568,210 shares outstanding)
Capital in excess of par value
Retained earnings
Accumulated other comprehensive loss
Total stockholders’ equity
Total liabilities and equity
See notes to the Consolidated Financial Statements.
F-8
December 31
2021
2020
(In thousands, except share data)
$
$
$
$
86,005 $
25,667
5,605
54,085
15,054
2,016
14,621
203,053
193,167
31,774
19,090
8,911
51,225
507,220 $
12,208 $
741
—
2,527
1,820
16,339
4,082
8,299
46,016
18,183
9,733
42,131
6,605
14,792
10,113
7,531
155,104
88,450
18,894
4,764
47,551
17,615
2,564
8,308
188,146
172,417
35,330
28,978
10,324
40,984
476,179
5,522
125
20,000
2,112
1,844
14,430
941
7,283
52,257
24,353
11,196
39,888
8,838
17,550
9,413
12,060
175,555
5,616
5,490
1,567
16,331
336,778
(8,176)
352,116
507,220 $
1,568
10,895
294,270
(11,599)
300,624
476,179
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
Operating Activities
Net income
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion and amortization
Amortization of deferred financing fees
Deferred income taxes
Stock-based compensation
Gain on sale of assets
Inventory impairment charge
Other asset impairment charges
Other
Working capital changes:
Affiliates receivable/payable
Accounts receivable
Inventories
Other current assets
Accounts payable
Income taxes receivable/payable
Other current liabilities
Net cash provided by (used for) operating activities
Investing Activities
Expenditures for property, plant and equipment
Acquisition of mineral interests
Proceeds from the sale of assets
Purchase of equity securities
Other
Net cash used for investing activities
Financing Activities
Net (reductions) additions to revolving credit agreement
Additions to long-term debt
Reductions to long-term debt
Cash dividends paid
Purchase of treasury shares
Other
Net cash (used for) provided by financing activities
Cash and Cash Equivalents
Total decrease for the year
Balance at the beginning of the year
Balance at the end of the year
See notes to the Consolidated Financial Statements.
F-9
Year Ended December 31
2021
2020
(In thousands)
$
48,125 $
14,793
23,085
326
(3,553)
5,561
(60)
—
—
18,114
334
7,517
3,078
(269)
1,973
8,359
1,647
(3,786)
495
(13,685)
(6,534)
3,320
7,445
2,699
6,004
74,875
(39,230)
(5,331)
633
—
(219)
20
42
(9,361)
(2,582)
(10,622)
(10,790)
(19,306)
(2,486)
(30,187)
(14,181)
571
(2,000)
(187)
(44,147)
(45,984)
(26,000)
3,634
(3,435)
(5,617)
—
(1,755)
(33,173)
14,000
7,427
(1,354)
(5,375)
(1,002)
332
14,028
(2,445)
88,450
(34,442)
122,892
$
86,005 $
88,450
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF EQUITY
Class A
Common
Stock
Class B
Common
Stock
Capital in
Excess of
Par Value
Retained
Earnings
Accumulated
Other
Comprehensive
(Loss) Income
Total
Stockholders'
Equity
(In thousands, except per share data)
8,911 $ 284,852 $
—
2,954
(11,337) $
—
(970)
—
—
14,793
—
—
1,569 $
—
(1)
—
—
—
—
—
1,568 $
—
(1)
—
—
—
—
1,567 $
—
—
—
(5,375)
—
—
10,895 $ 294,270 $
—
5,436
—
—
48,125
—
—
—
—
(5,617)
—
—
16,331 $ 336,778 $
—
(697)
435
(11,599) $
—
—
—
—
2,851
572
(8,176) $
289,392
3,078
—
(1,002)
14,793
(5,375)
(697)
435
300,624
5,561
—
48,125
(5,617)
2,851
572
352,116
$
Balance, January 1, 2020
Stock-based compensation
Conversion of Class B to Class A shares
Purchase of treasury shares
Net income
Cash dividends on Class A and Class B common stock:
$0.7675 per share
Current period other comprehensive income, net of tax
Reclassification adjustment to net income, net of tax
Balance, December 31, 2020
Stock-based compensation
Conversion of Class B to Class A shares
Net income
Cash dividends on Class A and Class B common stock:
$0.7850 per share
Current period other comprehensive income, net of tax
Reclassification adjustment to net income, net of tax
Balance, December 31, 2021
$
$
See notes to the Consolidated Financial Statements.
5,397 $
124
1
(32)
—
—
—
—
5,490 $
125
1
—
—
—
—
5,616 $
F-10
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
NOTE 1—Principles of Consolidation and Nature of Operations
The Consolidated Financial Statements include the accounts of NACCO Industries, Inc.® (“NACCO”) and its wholly owned
subsidiaries (collectively, the “Company”). NACCO brings natural resources to life by delivering aggregates, minerals, reliable
fuels and environmental solutions through its robust portfolio of NACCO Natural Resources businesses. The Company operates
under three business segments: Coal Mining, North American Mining ("NAMining") and Minerals Management. The Coal
Mining segment operates surface coal mines for power generation companies and an activated carbon producer. The NAMining
segment is a trusted mining partner for producers of aggregates, lithium and other minerals. The Minerals Management segment
promotes the development of mineral interests. In addition, Mitigation Resources of North America® ("Mitigation Resources")
provides stream and wetland mitigation solutions.
The Company also has items not directly attributable to a reportable segment. Intercompany accounts and transactions are
eliminated in consolidation. See Note 15 to the Consolidated Financial Statements for further discussion of segment reporting.
The Company’s operating segments are further described below:
Coal Mining Segment
The Coal Mining segment, operating as The North American Coal Corporation® ("NACoal"), operates surface coal mines under
long-term contracts with power generation companies and an activated carbon producer pursuant to a service-based business
model. Coal is surface mined in North Dakota, Texas, Mississippi, Louisiana and through September 30, 2021, on the Navajo
Nation in New Mexico. Each mine is fully integrated with its customer's operations.
As of December 31, 2021, the Company's operating coal mines were: The Coteau Properties Company (“Coteau”), Coyote
Creek Mining Company, LLC (“Coyote Creek”), Demery Resources Company, LLC (“Demery”), The Falkirk Mining
Company (“Falkirk”), Mississippi Lignite Mining Company (“MLMC”) and The Sabine Mining Company (“Sabine”).
The contract mining agreement between Bisti Fuels Company, LLC (“Bisti”) and its customer, Navajo Transitional Energy
Company ("NTEC") was terminated effective September 30, 2021. As required under the agreement, NTEC paid the Company
a termination fee of $10.3 million reported on the line Contract termination settlement on the Consolidated Statements of
Operations. As of October 1, 2021, NTEC assumed control and responsibility for operation and all reclamation of the Navajo
Mine.
The Coteau Properties Company (“Coteau”) operates the Freedom Mine in North Dakota. All coal production from the
Freedom Mine is delivered to Basin Electric Power Cooperative (“Basin Electric”). Basin Electric utilizes the coal at the Great
Plains Synfuels Plant (the “Synfuels Plant”), Antelope Valley Station and Leland Olds Station. The Synfuels Plant is a coal
gasification plant, owned by Dakota Gasification Company (“Dakota Gas’), a subsidiary of Basin Electric, that manufactures
synthetic natural gas and produces fertilizers, solvents, phenol, carbon dioxide, and other chemical products for sale. During
2020, Basin Electric informed Coteau that it is considering changes that may result in modifications to its Synfuels Plant that
could potentially reduce or eliminate coal requirements at the Synfuels Plant. During August 2021, Bakken Energy (“Bakken”)
and Basin Electric signed a non-binding term sheet to transfer ownership of the assets of Dakota Gas to Bakken. Bakken stated
the closing date is expected to be April 1, 2023. As part of the term sheet between Basin Electric and Bakken, Basin Electric
indicated that the Synfuels Plant will continue existing operations through 2025. The closing is subject to the satisfaction of
specified conditions. Basin Electric is also considering other options for the Synfuels Plant if the transaction with Bakken does
not close. Basin Electric indicated that if it decides to proceed with any changes that could reduce or eliminate the use of coal,
the feedstock change is not expected to occur before 2026.
Falkirk operates the Falkirk Mine in North Dakota. Falkirk is the sole supplier of lignite coal to the Coal Creek Station power
plant pursuant to a contract under which Falkirk also supplies approximately 0.3 million tons of lignite coal per year to
Spiritwood Station power plant. Coal Creek Station and Spiritwood Station are owned by Great River Energy (“GRE”). In May
2020, GRE announced its intent to sell or retire Coal Creek Station and modify Spiritwood Station to be fueled by natural gas.
During June 2021, GRE entered into an agreement to sell Coal Creek Station and the adjacent high-voltage direct current
transmission line to Bismarck, North Dakota-based Rainbow Energy Center, LLC (“Rainbow Energy”) and its affiliates. The
F-11
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
closing of this sale is subject to the satisfaction of certain conditions and presently, the transaction is expected to close during
the second quarter of 2022.
Falkirk meets the definition of a variable interest entity (“VIE”). The Company concluded that GRE’s May 2020 and June 2021
announcements were not reconsideration events; however, the completion of the Rainbow Energy transaction will result in a
reconsideration event. As the terms of the contract between Falkirk and Rainbow Energy are substantially the same as the terms
of the contract between Falkirk and GRE, Falkirk is expected to remain a VIE and Rainbow Energy will become the primary
beneficiary; therefore, NACCO will continue to account for Falkirk under the equity method.
Upon completion of the sale of Coal Creek Station, the existing Coal Sales Agreement, the existing Mortgage and Security
Agreement and the existing Option Agreement between GRE and Falkirk will terminate. Falkirk and GRE have entered into a
termination and release of claims agreement. Upon completion of the sale of Coal Creek Station, GRE will pay Falkirk
$14.0 million in cash, as well as transfer ownership of an office building located in Bismarck, North Dakota, and convey
membership units in Midwest AgEnergy to NACoal. NACCO currently holds a $5.0 million investment in Midwest AgEnergy,
which operates two ethanol facilities in North Dakota.
If GRE's efforts to sell the power plant are successful, a new Coal Sales Agreement (“CSA”) between Falkirk and Rainbow
Energy will become effective and Falkirk will supply all coal requirements of Coal Creek Station concurrent with Rainbow
Energy’s acquisition of the power plant. Falkirk will no longer make any coal deliveries to GRE’s Spiritwood Station. Falkirk
will be paid a management fee and Rainbow Energy will be responsible for funding all mine operating costs and directly or
indirectly providing all of the capital required to operate the mine. The CSA specifies that Falkirk will perform final mine
reclamation, which will be funded in its entirety by Rainbow Energy. The initial production period is expected to run ten years
from the effective date of the CSA, but the CSA may be extended or terminated early under certain circumstances. If Rainbow
Energy terminates the CSA and closes Coal Creek Station before 2027, Falkirk will be entitled to an additional payment from
GRE under the terms of the termination and release of claims agreement. The additional payment amount ranges from
$8 million if the closure occurs before 2024 to $2 million if the closure occurs in 2026. To support the transfer to new
ownership, Falkirk has agreed to a reduction in the current per ton management fee from the effective date of the new CSA
through May 31, 2024. After May 31, 2024, the per ton management fee increases to a higher base in line with current fee
levels, and thereafter adjusts annually according to an index which tracks broad measures of U.S. inflation.
If GRE’s efforts to sell the power plant are not successful and GRE elects to prematurely close Coal Creek Station, the early
termination of the CSA would have a material adverse effect on the Company's business, financial condition and results of
operations.
Sabine operates the Sabine Mine in Texas. All production from Sabine is delivered to Southwestern Electric Power Company's
(“SWEPCO”) Henry W. Pirkey Plant (the “Pirkey Plant”). SWEPCO is an American Electric Power (“AEP”) company. During
2020, AEP announced its intent to retire the Pirkey Plant in 2023. SWEPCO expects deliveries from Sabine to continue until
the first quarter of 2023 at which time Sabine expects to begin final reclamation. Funding for mine reclamation is the
responsibility of SWEPCO.
During 2020, Caddo Creek Resources Company, LLC (“Caddo Creek”) ceased all mining and delivery of lignite and
commenced mine reclamation. Funding for mine reclamation is the responsibility of a subsidiary of Advanced Emissions
Solutions (“AES”). Caddo Creek entered into a contract with a subsidiary of AES to perform the required mine reclamation.
The reclamation at Caddo Creek is expected to be substantially complete during the first half of 2022.
During 2020, the contract mining agreement between Camino Real Fuels, LLC (“Camino Real”) and its customer, Dos
Republicas Coal Partnership (“DRCP”), terminated and resulted in mine closure. Funding for mine reclamation is the
responsibility of DRCP.
At all operating coal mines other than MLMC, the Company is paid a management fee per ton of coal or heating unit (MMBtu)
delivered. Each contract specifies the indices and mechanics by which fees change over time, generally in line with broad
measures of U.S. inflation. The customers are responsible for funding all mine operating costs, including final mine
reclamation, and directly or indirectly provide all of the capital required to build and operate the mine. This contract structure
eliminates exposure to spot coal market price fluctuations while providing income and cash flow with minimal capital
investment. Other than at Coyote Creek, debt financing provided by or supported by the customers is without recourse to
NACCO and NACoal. See Note 17 for further discussion of Coyote Creek's guarantees.
F-12
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
All operating coal mines other than MLMC meet the definition of a VIE. In each case, NACCO is not the primary beneficiary
of the VIE as it does not exercise financial control; therefore, NACCO does not consolidate the results of these operations
within its financial statements. Instead, these contracts are accounted for as equity method investments. The income before
income taxes associated with these VIEs is reported as Earnings of unconsolidated operations on the Consolidated Statements
of Operations, and the Company’s investment is reported on the line Investments in Unconsolidated Subsidiaries in the
Consolidated Balance Sheets. The mines that meet the definition of a VIE are referred to collectively as the “Unconsolidated
Subsidiaries.” For tax purposes, the Unconsolidated Subsidiaries are included within the NACCO consolidated U.S. tax return;
therefore, the income tax expense line on the Consolidated Statements of Operations includes income taxes related to these
entities. See Note 17 for further information on the Unconsolidated Subsidiaries.
The Company performs contemporaneous reclamation activities at each mine in the normal course of operations. Under all of
the Unconsolidated Subsidiaries’ contracts, the customer has the obligation to fund final mine reclamation activities. Under
certain contracts, the Unconsolidated Subsidiary holds the mine permit and is therefore responsible for final mine reclamation
activities. To the extent the Unconsolidated Subsidiary performs such final reclamation, it is compensated for providing those
services in addition to receiving reimbursement from customers for costs incurred. At Caddo Creek, the terms of the contract to
perform mine reclamation contain a fixed-price component and therefore, Caddo Creek no longer meets the VIE criteria. As a
result, Caddo Creek is consolidated within the Company's financial statements.
The MLMC contract is the only operating coal contract in which the Company is responsible for all operating costs, capital
requirements and final mine reclamation; therefore, MLMC is consolidated within NACCO’s financial statements. MLMC sells
coal to its customer at a contractually agreed-upon price which adjusts monthly, primarily based on changes in the level of
established indices which reflect general U.S. inflation rates. Profitability at MLMC is affected by customer demand for coal
and changes in the indices that determine sales price and actual costs incurred. As diesel fuel is heavily weighted among the
indices used to determine the coal sales price, fluctuations in diesel fuel prices can result in significant fluctuations in earnings
at MLMC.
NAMining Segment
The NAMining segment provides value-added contract mining and other services for producers of aggregates, lithium and other
minerals. The segment is a primary platform for the Company’s growth and diversification of mining activities outside of the
coal industry. NAMining provides contract mining services for independently owned mines and quarries, creating value for its
customers by performing the mining aspects of its customers’ operations. This allows customers to focus on their areas of
expertise: materials handling and processing, product sales and distribution. NAMining historically operated primarily at
limestone quarries in Florida, but is focused on expanding outside of Florida, mining materials other than limestone and
expanding the scope of mining operations provided to its customers.
NAMining utilizes both fixed price and management fee contract structures. Certain of the entities within the NAMining
segment are VIEs and are accounted for under the equity method as Unconsolidated Subsidiaries. See Note 17 for further
discussion.
Minerals Management Segment
The Minerals Management segment derives income primarily by leasing its royalty and mineral interests to third-party
exploration and production companies, and, to a lesser extent, other mining companies, granting them the rights to explore,
develop, mine, produce, market and sell gas, oil, and coal in exchange for royalty payments based on the lessees' sales of those
minerals. During 2021 and 2020, the Minerals Management segment acquired mineral interests, primarily in the Eagle Ford and
Permian Basins in Texas and intends to make future acquisitions of mineral and royalty interests that meet the Company’s
acquisition criteria as part of its growth strategy. See Note 20 for further discussion of Mineral Management's acquisitions.
The Company’s legacy royalty and mineral interests are located in Ohio (Utica and Marcellus shale natural gas), Louisiana
(Haynesville shale and Cotton Valley formation natural gas), Texas (Cotton Valley and Austin Chalk formation natural gas),
Mississippi (coal), Pennsylvania (coal, coalbed methane and Marcellus shale natural gas), Alabama (coal, coalbed methane and
natural gas) and North Dakota (coal, oil and natural gas). The majority of the Company’s legacy reserves were acquired as part
of its historical coal mining operations.
F-13
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
NOTE 2—Significant Accounting Policies
Use of Estimates: The preparation of financial statements in conformity with U.S. generally accepted accounting principles
requires management to make estimates and judgments. These estimates and judgments affect the reported amounts of assets
and liabilities and the disclosure of contingent assets and liabilities (if any) at the date of the financial statements and the
reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Cash and Cash Equivalents: Cash and cash equivalents include cash in banks and highly liquid investments with original
maturities of three months or less.
Inventories: Inventories are stated at the lower of cost and net realizable value. The weighted average method is used for
inventory valuation.
Property, Plant and Equipment, Net: Property, plant and equipment are initially recorded at cost. Depreciation, depletion and
amortization are provided in amounts sufficient to amortize the cost of the assets, including assets recorded under finance
leases, over their estimated useful lives using the straight-line method or the units-of-production method. Buildings and
building improvements are depreciated over the life of the mine, which is generally 30 years. Estimated lives for machinery and
equipment range from three to 15 years. The units-of-production method is used to amortize certain assets based on estimated
recoverable tonnages. Repairs and maintenance costs are expensed when incurred, unless such costs extend the estimated useful
life of the asset, in which case such costs are capitalized and depreciated. Asset retirement costs associated with asset retirement
obligations are capitalized with the carrying amount of the related long-lived asset and depreciated over the asset's estimated
useful life.
Royalty Interests in Oil and Natural Gas Properties: The Company follows the successful efforts method of accounting for
its royalty and mineral interests. Under this method, costs to acquire mineral and royalty interests in oil and natural gas
properties are capitalized when incurred. Acquisitions of royalty interests of oil and natural gas properties are considered asset
acquisitions and are recorded at cost. As an owner of mineral and royalty interests and not working interests, the Company is
not required to make capital expenditures and did not make capital expenditures to convert proved undeveloped reserves from
undeveloped to developed.
Acquisition costs of proved royalty and mineral interests are amortized using the units of production method over the life of the
property, which is estimated using proved reserves. For purposes of amortization, interests in oil and natural gas properties are
grouped in a reasonable aggregation of properties with common geological structural features or stratigraphic condition.
The Company reviews and evaluates its royalty interests in oil and natural gas properties for impairment when events or
changes in circumstances indicate that the related carrying amounts may not be recoverable. Proved oil and gas properties are
reviewed for impairment when events and circumstances indicate a potential decline in the fair value of such properties below
the carrying value, such as a downward revision of the reserve estimates or lower commodity prices. When such events or
changes in circumstances occur, the Company estimates the undiscounted future cash flows expected in connection with the
properties and compares such future cash flows to the carrying amounts of the properties to determine if the carrying amounts
are recoverable. If the carrying value of the properties is determined to not be recoverable based on the undiscounted cash
flows, an impairment charge is recognized by comparing the carrying value to the estimated fair value of the properties.
See Note 20 for further discussion of the Company's royalty and mineral interests.
Long-Lived Assets: The Company periodically evaluates long-lived assets for impairment when changes in circumstances or
the occurrence of certain events indicate the carrying amount of an asset or asset group may not be recoverable. Upon
identification of indicators of impairment, the Company evaluates the carrying value of the asset by comparing the estimated
future undiscounted cash flows generated from the use of the asset or asset group and its eventual disposition with the asset's
net carrying value. If the carrying value of an asset is considered impaired, an impairment charge is recorded for the amount
that the carrying value of the long-lived asset or asset group exceeds its fair value. Fair value is estimated as the price that
would be received to sell an asset or paid to transfer a liability in an orderly transaction between market participants at the
measurement date. See Note 9 for further discussion of the Company's nonrecurring fair value measurements.
At MLMC, the costs of mining operations are not reimbursed by MLMC's customer. As such, increased costs at MLMC or
decreased revenues could materially reduce the Company's profitability. Any reduction in customer demand at MLMC,
including reductions related to reduced mechanical availability of the customer’s power plant, would adversely affect the
Company's operating results and could result in significant impairments. MLMC has approximately $136 million of long-lived
assets, including property, plant and equipment and its coal supply agreement intangible asset, which are subject to periodic
impairment analyses and review. Identifying and assessing whether impairment indicators exist, or if events or changes in
F-14
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
circumstances have occurred, including assumptions about future power plant dispatch levels, changes in future sales price,
operating costs and other factors that impact anticipated revenue and customer demand, requires significant judgment. Actual
future operating results could differ significantly from these estimates, which may result in an impairment charge in a future
period, which could have a substantial impact on the Company’s results of operations.
Coal Supply Agreement: The coal supply agreement represents a long-term supply agreement with MLMC's customer and
was recorded based on the fair value at the date of acquisition. The coal supply agreement is amortized based on units of
production over the term of the agreement, which expires in 2032. The Company reviews identified intangible assets for
impairment when changes in circumstances or the occurrence of certain events indicate potential impairment.
Self-insurance Liabilities: The Company is generally self-insured for medical claims, certain workers’ compensation claims
and certain closed mine liabilities. An estimated provision for claims reported and for claims incurred but not yet reported under
the self-insurance programs is recorded and revised periodically based on industry trends, historical experience and
management judgment. In addition, industry trends are considered within management's judgment for valuing claims. Changes
in assumptions for such matters as legal judgments and settlements, inflation rates, medical costs and actual experience could
cause estimates to change in the near term.
Revenue Recognition: See Note 3 to the Consolidated Financial Statements for discussion of revenue recognition.
Stock Compensation: The Company maintains long-term incentive programs that allow for the grant of shares of Class A
common stock, subject to restrictions, as a means of retaining and rewarding selected employees for long-term performance and
to increase ownership in the Company. Shares awarded under the plans are fully vested and entitle the stockholder to all rights
of common stock ownership except that shares may not be assigned, pledged or otherwise transferred during the restriction
period. In general, for shares awarded for years ended December 31, 2021 and December 31, 2020, the restriction period ends
at the earliest of (i) three years after the participant's retirement date, (ii) three, five or ten years from the award date, or (iii) the
participant's death or permanent disability. Pursuant to the plans, the Company issued 138,306 and 79,380 shares related to the
years ended December 31, 2021 and 2020, respectively. After the issuance of these shares, there were 561,694 shares of Class
A common stock available for issuance under these plans. Compensation expense related to these share awards was $4.1
million ($3.2 million net of tax) and $2.0 million ($1.6 million net of tax) for the years ended December 31, 2021 and 2020,
respectively. Compensation expense represents fair value based on the market price of the shares of Class A common stock at
the grant date.
The Company also has a stock compensation plan for non-employee directors of the Company under which a portion of the
annual retainer for each non-employee director is paid in restricted shares of Class A common stock. For the year ended
December 31, 2021, $105,000 ($150,000 for the Chairman) of the non-employee director's annual retainer of $167,000
($250,000 for the Chairman) was paid in restricted shares of Class A common stock. For the year ended December 31, 2020,
$100,000 ($150,000 for the Chairman) of the non-employee director's annual retainer of $162,000 ($250,000 for the Chairman)
was paid in restricted shares of Class A common stock. Shares awarded under the plan are fully vested and entitle the
stockholder to all rights of common stock ownership except that shares may not be assigned, pledged, hypothecated or
otherwise transferred during the restriction period. In general, the restriction period ends at the earliest of (i) ten years from the
award date, (ii) the date of the director's death or permanent disability, (iii) five years (or earlier with the approval of the Board
of Directors) after the director's date of retirement from the Board of Directors, (iv) the date the director has both retired from
the Board of Directors and has reached age 70, or (v) at such other time as determined by the Board of Directors in its sole and
absolute discretion. Pursuant to this plan, the Company issued 45,223 and 42,744 shares related to the years ended
December 31, 2021 and 2020, respectively. In addition to the mandatory retainer fee received in restricted stock, directors may
elect to receive shares of Class A common stock in lieu of cash for up to 100% of the balance of their annual retainer,
committee retainer and any committee chairman's fees. These voluntary shares are not subject to any restrictions. Total shares
issued under voluntary elections were 753 in 2021 and 745 in 2020. After the issuance of these shares, there were 166,561
shares of Class A common stock available for issuance under this plan. Compensation expense related to these awards was
$1.3 million ($1.1 million net of tax) and $1.0 million ($0.8 million net of tax) for the years ended December 31, 2021 and
2020, respectively. Compensation expense represents fair value based on the market price of the shares of Class A common
stock at the grant date.
Financial Instruments: Financial instruments held by the Company include cash and cash equivalents, accounts receivable,
equity securities, accounts payable, revolving credit agreements and long-term debt.
Fair Value Measurements: The Company accounts for the fair value measurement of its financial assets and liabilities in
accordance with U.S. generally accepted accounting principles, which defines fair value as the price that would be received to
sell an asset or paid to transfer a liability in an orderly transaction between market participants at the measurement date.
F-15
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
A fair value hierarchy requires an entity to maximize the use of observable inputs, where available, and minimize the use of
unobservable inputs when measuring fair value.
Described below are the three levels of inputs that may be used to measure fair value:
Level 1 - Quoted prices in active markets that are accessible at the measurement date for identical assets or liabilities.
Level 2 - Observable prices that are based on inputs not quoted on active markets, but corroborated by market data.
Level 3 - Unobservable inputs are used when little or no market data is available.
The hierarchy is based upon the transparency of inputs to the valuation of an asset or liability as of the measurement date. The
classification of fair value measurements within the hierarchy is based upon the lowest level of input that is significant to the
measurement. See Note 9 for further discussion of fair value measurements.
NOTE 3—Revenue Recognition
Nature of Performance Obligations
At contract inception, the Company assesses the goods and services promised in its contracts with customers and identifies a
performance obligation for each promised good or service that is distinct. To identify the performance obligations, the
Company considers all of the goods or services promised in the contract regardless of whether they are explicitly stated or are
implied by customary business practices.
Each mine or mine area has a contract with its respective customer that represents a contract under ASC 606. For its
consolidated entities, the Company’s performance obligations vary by contract and consist of the following:
At MLMC, each MMBtu delivered during the production period is considered a separate performance obligation. Revenue is
recognized at the point in time that control of each MMBtu of lignite transfers to the customer. Fluctuations in revenue from
period to period generally result from changes in customer demand.
During 2020, Caddo Creek entered into a fixed-price contract to perform mine reclamation. The management service to perform
mine reclamation is the performance obligation accounted for as a series. Performance momentarily creates an asset that the
customer simultaneously receives and consumes; therefore, control is transferred to the customer over time. Revenue from this
contract is recognized over time utilizing the cost-to-cost method to measure the extent of progress toward completion of the
performance obligation. The Company believes the cost-to-cost method is the most appropriate method to measure progress and
that the rate at which costs are incurred to fulfill the contract best depicts the transfer of control to the customer. The extent of
progress towards completion is measured based on the ratio of costs incurred to date compared to total estimated costs at
completion, and revenue is recorded proportionally based on an estimated profit margin.
At NAMining, the management service to oversee the operation of the equipment and delivery of aggregates or other minerals
is the performance obligation accounted for as a series. Performance momentarily creates an asset that the customer
simultaneously receives and consumes; therefore, control is transferred to the customer over time. Consistent with the
conclusion that the customer simultaneously receives and consumes the benefits provided, an input-based measure of progress
is appropriate. As each month of service is completed, revenue is recognized for the amount of actual costs incurred, plus the
management fee or fixed fee and the general and administrative fee (as applicable). Fluctuations in revenue from period to
period result from changes in customer demand primarily due to increases and decreases in activity levels on individual
contracts and variances in reimbursable costs.
The Minerals Management segment enters into contracts which grant the right to explore, develop, produce and sell minerals
controlled by the Company. These arrangements result in the transfer of mineral rights for a period of time; however, no rights
to the actual land are granted other than access for purposes of exploration, development, production and sales. The mineral
rights revert back to the Company at the expiration of the contract.
Under these contracts, granting exclusive right, title, and interest in and to minerals, if any, is the performance obligation. The
performance obligation under these contracts represents a series of distinct goods or services whereby each day of access that is
provided is distinct. The transaction price consists of a variable sales-based royalty and, in certain arrangements, a fixed
component in the form of an up-front lease bonus payment. As the amount of consideration the Company will ultimately be
entitled to is entirely susceptible to factors outside its control, the entire amount of variable consideration is constrained at
contract inception. The Company believes that the pricing provisions of royalty contracts are customary in the industry. Up-
F-16
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
front lease bonus payments represent the fixed portion of the transaction price and are recognized over the primary term of the
contract, which is generally five years.
Significant Judgments
The Company’s contracts with its customers contain different types of variable consideration including, but not limited to,
management fees that adjust based on volumes or MMBtu delivered, however, the terms of these variable payments relate
specifically to the Company's efforts to satisfy one or more, but not all of, the performance obligations (or to a specific outcome
from satisfying the performance obligations) in the contract. Therefore, the Company allocates each variable payment (and
subsequent changes to that payment) entirely to the specific performance obligation to which it relates. Management fees, as
well as general and administrative fees, are also adjusted based on changes in specified indices (e.g., CPI) to compensate for
general inflation changes. Index adjustments, if applicable, are effective prospectively.
Recognition of revenue and recognition of profit related to the Caddo Creek contract requires the use of assumptions and
estimates related to the total contract value, the total cost at completion, and the measurement of progress towards completion
of the performance obligation. Due to the nature of the contract, developing the estimated total contract value and total cost at
completion requires the use of significant judgment. The total contract value includes variable consideration. The Company
includes variable consideration in the transaction price at the most likely amount to be earned, based upon the Company’s
assessment of expected performance. The Company records these amounts only to the extent it is probable that a significant
reversal of cumulative revenue recognized will not occur when the uncertainty associated with the variable consideration is
resolved.
Cost Reimbursement
Certain contracts include reimbursement from customers of actual costs incurred for the purchase of supplies, equipment and
services in accordance with contractual terms. Such reimbursable revenue is variable and subject to uncertainty, as the amounts
received and timing thereof is highly dependent on factors outside of the Company’s control. Accordingly, reimbursable
revenue is fully constrained and not recognized until the uncertainty is resolved, which typically occurs when the related costs
are incurred on behalf of a customer. The Company is considered a principal in such transactions and records the associated
revenue at the gross amount billed to the customer with the related costs recorded as an expense within cost of sales.
Prior Period Performance Obligations
The Company records royalty income in the month production is delivered to the purchaser. As a non-operator, the Company
has limited visibility into when new wells start producing and production statements may not be received for 30 to 90 days or
more after the date production is delivered. As a result, the Company is required to estimate the amount of production delivered
to the purchaser of the product and the price that will be received for the sale of the product. The expected sales volumes and
prices for these properties are estimated and recorded in "Trade accounts receivable" in the accompanying Consolidated
Balance Sheets. The difference between the Company’s estimates and the actual amounts received is recorded in the month that
payment is received from the third-party lessee. During 2021, the Company recognized $1.8 million of variable consideration
that was previously constrained due to uncertainty of collectability. During 2020, royalty income recognized in the reporting
period related to performance obligations satisfied in prior reporting periods was immaterial.
Disaggregation of Revenue
In accordance with ASC 606-10-50, the Company disaggregates revenue from contracts with customers into major goods and
service lines and timing of transfer of goods and services. The Company determined that disaggregating revenue into these
categories achieves the disclosure objective of depicting how the nature, amount, timing, and uncertainty of revenue and cash
flows are affected by economic factors. The Company’s business consists of the Coal Mining, NAMining and Minerals
Management segments as well as Unallocated Items. See Note 15 to the Consolidated Financial Statements for further
discussion of segment reporting.
F-17
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
The following table disaggregates revenue by major sources for the years ended December 31:
Major Goods/Service Lines
Coal Mining
NAMining
Minerals Management
Unallocated Items
Eliminations
Total revenues
Timing of Revenue Recognition
Goods transferred at a point in time
Services transferred over time
Total revenues
Contract Balances
2021
2020
91,851 $
69,924
31,003
4,695
(5,627)
191,846 $
72,088
42,392
14,721
2,133
(2,902)
128,432
80,515 $
111,331
191,846 $
68,073
60,359
128,432
$
$
$
$
The opening and closing balances of the Company’s current and long-term contract liabilities and receivables are as follows:
Trade accounts
receivable
Contract asset
(long-term)
Contract liability
(current)
Contract liability
(long-term)
Balance at January 1, 2021
Balance at December 31, 2021
Increase (decrease)
$
$
18,894
25,667
6,773
$
$
4,984
5,985
1,001
$
$
941
4,082
3,141
$
$
3,626
488
(3,138)
Contract balances
As described above, the Company enters into royalty contracts that grant exclusive right, title, and interest in and to minerals.
The transaction price consists of a variable sales-based royalty and, in certain arrangements, a fixed component in the form of
an up-front lease bonus payment. The timing of the payment of the fixed portion of the transaction price is upfront, however,
the performance obligation is satisfied over the primary term of the contract, which is generally five years. Therefore, at the
time any such up-front payment is received, a contract liability is recorded which represents deferred revenue. The difference
between the opening and closing balance of this contract liability, which is shown above, primarily results from the difference
between new lease bonus payments received and amortization of up-front lease bonus payments received in previous periods.
The amount of revenue recognized in the years ended December 31, 2021 and December 31, 2020 that was included in the
opening contract liability was $1.4 million and $0.9 million, respectively. This revenue consists of up-front lease bonus
payments received under royalty contracts that are recognized over the primary term of the royalty contracts, which are
generally five years. The Company expects to recognize $4.1 million in 2022, $0.3 million in 2023, $0.1 million in 2024, and
de minimis amounts in 2025 and 2026 related to the contract liability remaining at December 31, 2021. The difference between
the opening and closing balances of the Company’s contract balances results from the timing difference between the
Company’s performance and the customer’s payment.
The Company has no contract assets recognized from the costs to obtain or fulfill a contract with a customer.
F-18
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
NOTE 4—Inventories
Inventories are summarized as follows:
Coal
Mining supplies
Total inventories
December 31
2021
2020
$
$
19,352 $
34,733
54,085 $
17,695
29,856
47,551
During 2020, the Company recorded a $2.0 million inventory impairment charge in the line “Cost of sales” in the
accompanying Consolidated Statements of Operations as mining costs exceeded net realizable value at MLMC.
NOTE 5—Property, Plant and Equipment, Net
Property, plant and equipment, net includes the following:
Coal lands and real estate
Mineral interests
Plant and equipment
Property, plant and equipment, at cost
Less allowances for depreciation, depletion and amortization
December 31
2021
2020
$
52,011 $
19,512
264,110
335,633
142,466
$
193,167 $
50,887
14,181
231,190
296,258
123,841
172,417
Total depreciation, depletion and amortization expense on property, plant and equipment was $19.5 million and $15.5 million
during 2021 and 2020, respectively.
NOTE 6—Intangible Assets
The Company has a coal supply agreement intangible asset which is subject to amortization based on units of production over
the term of the lignite sales agreement which expires in 2032. The gross and net balances are set forth in the following table:
Balance at December 31, 2021
Coal supply agreement
Balance at December 31, 2020
Coal supply agreement
Gross Carrying
Amount
Accumulated
Amortization
Net
Balance
$
$
84,200 $
(52,426) $
31,774
84,200 $
(48,870) $
35,330
Amortization expense for intangible assets was $3.6 million and $2.6 million in 2021 and 2020, respectively.
Expected annual amortization expense of the coal supply agreement for the next five years is $3.1 million in 2022 through
2026.
NOTE 7—Asset Retirement Obligations
The Company’s obligations associated with the retirement of long-lived assets are recognized at fair value at the time the legal
obligations are incurred. Upon initial recognition of a liability, a corresponding amount is capitalized as part of the carrying
value of the related long-lived asset and is depreciated either by the straight-line method or the units-of-production method. The
F-19
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
liability is accreted each period until the liability is settled, at which time the liability is removed. If the liability is settled for an
amount other than the recorded amount, a gain or loss is recognized.
The Company's asset retirement obligations are principally for costs to close its surface mines and reclaim the land it has
disturbed as a result of its normal mining activities as well as for costs to dismantle certain mining equipment at the end of the
life of the mine. Management’s estimate involves a high degree of subjectivity. In particular, the obligation’s fair value is
determined using a discounted cash flow technique and is based upon mining permit requirements and various assumptions
including credit adjusted risk-free-rates, estimates of disturbed acreage, life of the mine, estimated reclamation costs, the
application of various environmental laws and regulation and assumptions regarding equipment productivity. The Company
reviews its asset retirement obligations at each mine site at least annually and makes necessary adjustments for permit changes
and for revisions of estimates of the timing and extent of reclamation activities and cost estimates.
The accretion of the liability is being recognized over the estimated life of each individual asset retirement obligation and is
recorded in the line “Cost of sales” in the accompanying Consolidated Statements of Operations. The associated asset is
recorded in “Property, Plant and Equipment, net” in the accompanying Consolidated Balance Sheets. The depreciation of the
asset is recorded in the line “Cost of sales” in the accompanying Consolidated Statements of Operations.
A reconciliation of the Company's beginning and ending aggregate carrying amount of the asset retirement obligations are as
follows:
Balance at January 1, 2020
Liabilities incurred during the period
Liabilities settled during the period
Accretion expense
Revision of estimated cash flows
Balance at December 31, 2020
Liabilities settled during the period
Accretion expense
Revision of estimated cash flows
Balance at December 31, 2021
Coal Mining
NAMining
Unallocated
Items
NACCO
Consolidated
$
$
$
19,015 $
9,809
(5,977)
1,793
400
25,040 $
(184)
1,996
46
26,898 $
604 $
—
—
—
(604)
— $
—
—
—
— $
17,240 $
—
(732)
1,022
(838)
16,692 $
(869)
1,304
(74)
17,053 $
36,859
9,809
(6,709)
2,815
(1,042)
41,732
(1,053)
3,300
(28)
43,951
Asset retirement obligations are incurred at the time development of a new mine or mine area commences. During 2020,
MLMC began development of a new mine area and as such, recorded an additional $9.8 million asset retirement obligation and
a corresponding $9.8 million asset was capitalized as a component of Property, plant and equipment, net. The asset retirement
obligation’s fair value was determined using a discounted cash flow technique and is based upon permit requirements and
various estimates and assumptions that would be used by market participants, including estimates of disturbed acreage,
reclamation costs and assumptions regarding equipment productivity.
Centennial Natural Resources (“Centennial”) ceased coal production at the end of 2015. During 2020, the Company transferred
the mine permits for certain Centennial mines to an unrelated third party. As a result of the transfer of the mine permits, the
Company was relieved of the associated mine reclamation obligations and therefore recorded a $4.8 million reduction to
Centennial's asset retirement obligation, included in "Liabilities settled during the period" in the table above. As part of the
transfer of the mine permits, the Company also paid $3.8 million of cash, recorded $1.4 million in Other assets for amounts
owed to Centennial from the third-party acquirer, and recognized $2.4 million in Other long-term liabilities in the Consolidated
Balance Sheets. The Other long-term liabilities are primarily associated with amounts due to the third-party acquirer upon
replacement of outstanding letters of credit.
Bellaire Corporation (“Bellaire”) is a non-operating subsidiary of the Company with legacy liabilities relating to closed mining
operations, primarily former Eastern U.S. underground coal mining operations. These legacy liabilities include obligations for
water treatment and other environmental remediation that arose as part of the normal course of closing these underground
mining operations. The accretion of the liability is recognized over the estimated life of the asset retirement obligation and is
recorded in the line “Closed mine obligations” in the accompanying Consolidated Statements of Operations. Since Bellaire's
properties are no longer active operations, no associated asset has been capitalized.
F-20
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
Prior to 2020, Bellaire established a $5.0 million Mine Water Treatment Trust to provide a financial assurance mechanism in
order to assure the long-term treatment of post-mining discharges. The fair value of Bellaire's Mine Water Treatment assets,
which are recognized as a component of Other non-current assets on the Consolidated Balance Sheets, are $12.3 million and
$11.1 million at December 31, 2021 and December 31, 2020, respectively, and are legally restricted for purposes of settling the
Bellaire asset retirement obligation. See Note 9 for further discussion of the Mine Water Treatment Trust.
NOTE 8—Current and Long-Term Financing
Financing arrangements are obtained and maintained at the subsidiary level. NACCO has not guaranteed any borrowings of its
subsidiaries.
The following table summarizes the Company's available and outstanding borrowings:
Total outstanding borrowings of NACoal:
Revolving credit agreement
Other debt
Total debt outstanding
Current portion of borrowings outstanding
Long-term portion of borrowings outstanding
Total available borrowings, net of limitations, under revolving credit agreement
Unused revolving credit agreement
December 31
2021
2020
$
$
$
$
$
$
4,000
16,710
20,710
2,527
18,183
20,710
120,231
116,231
$
$
$
$
$
$
30,000
16,465
46,465
22,112
24,353
46,465
146,951
116,951
Weighted average stated interest rate on total borrowings
3.7 %
2.3 %
Annual maturities of total debt, excluding leases, are as follows:
2022
2023
2024
2025
2026
Thereafter
2,377
2,460
2,068
5,175
5,492
2,798
$
20,370
Interest paid on total debt was $1.6 million and $1.4 million during 2021 and 2020, respectively. Deferred financing fees of
$1.8 million were capitalized during 2021.
NACoal has a secured revolving line of credit of up to $150.0 million (the “NACoal Facility”) that was refinanced during 2021
and expires in November 2025. Borrowings outstanding under the NACoal Facility were $4.0 million at December 31, 2021. At
December 31, 2021, the excess availability under the NACoal Facility was $116.2 million, which reflects a reduction for
outstanding letters of credit of $29.8 million.
The NACoal Facility has performance-based pricing, which sets interest rates based upon NACoal achieving various levels of
debt to EBITDA ratios, as defined in the NACoal Facility. Borrowings bear interest at a floating rate plus a margin based on the
level of debt to EBITDA ratio achieved. The applicable margins, effective December 31, 2021, for base rate and LIBOR loans
were 1.25% and 2.25%, respectively. The NACoal Facility has a commitment fee which is based upon achieving various levels
F-21
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
of debt to EBITDA ratios. The commitment fee was 0.35% on the unused commitment at December 31, 2021. The weighted
average interest rate applicable to the NACoal Facility at December 31, 2021 was 4.50% including the floating rate margin.
The NACoal Facility contains restrictive covenants, which require, among other things, NACoal to maintain a maximum net
debt to EBITDA ratio of 2.75 to 1.00 and an interest coverage ratio of not less than 4.00 to 1.00. The NACoal Facility provides
the ability to make loans, dividends and advances to NACCO, with some restrictions based on maintaining a maximum debt to
EBITDA ratio of 1.50 to 1.00, or if greater than 1.50 to 1.00, a Fixed Charge Coverage Ratio of 1.10 to 1.00, in conjunction
with maintaining unused availability thresholds of borrowing capacity, as defined in the NACoal Facility, of $15.0 million. At
December 31, 2021, NACoal was in compliance with all financial covenants in the NACoal Facility.
The obligations under the NACoal Facility are guaranteed by certain of NACoal's direct and indirect, existing and future
domestic subsidiaries, and is secured by certain assets of NACoal and the guarantors, subject to customary exceptions and
limitations.
NACoal has a demand note payable to Coteau, one of the unconsolidated subsidiaries, which bears interest based on the
applicable quarterly federal short-term interest rate as announced from time to time by the Internal Revenue Service. At
December 31, 2021 and 2020, the balance of the note was $2.6 million and $4.4 million and the interest rate was 0.18% and
0.14%, respectively.
NACoal has six notes payable that are secured by eleven specified units of equipment, bear interest at a weighted average rate
of 4.03%, and expire at various dates through 2027. One note includes a principal payment of $4.4 million at the end of the
term on December 15, 2026. At December 31, 2021 and 2020, the outstanding balances of the notes were $13.8 million and
$10.6 million, respectively.
NOTE 9—Fair Value Disclosure
Recurring Fair Value Measurements: The following table presents the Company's assets accounted for at fair value on a
recurring basis:
Description
December 31, 2021
Fair Value Measurements at Reporting Date Using
Quoted Prices in
Active Markets for
Identical Assets
(Level 1)
Significant Other
Observable Inputs
(Level 2)
Significant
Unobservable
Inputs
(Level 3)
Assets:
Equity securities
$
$
16,070
16,070
$
$
16,070
16,070
$
$
—
—
$
$
—
—
Description
December 31, 2020
Fair Value Measurements at Reporting Date Using
Quoted Prices in
Active Markets for
Identical Assets
(Level 1)
Significant Other
Observable Inputs
(Level 2)
Significant
Unobservable
Inputs
(Level 3)
Assets:
Equity securities
$
$
13,164
13,164
$
$
13,164
13,164
$
$
—
—
$
$
—
—
Bellaire's Mine Water Treatment Trust invests in available for sale securities that are reported at fair value based upon quoted
market prices in active markets for identical assets; therefore, they are classified as Level 1 within the fair value hierarchy. The
Mine Water Treatment Trust realized a gain of $1.7 million and $1.2 million in the years ended December 31, 2021 and 2020,
respectively. See Note 7 for further discussion of Bellaire's Mine Water Treatment Trust.
F-22
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
During 2020, the Company invested $2.0 million in equity securities of a public company with a diversified portfolio of royalty
producing mineral interests. The investment is reported at fair value based upon quoted market prices in active markets for
identical assets; therefore, it is classified as Level 1 within the fair value hierarchy. The Company recognized a gain of $1.7
million and $0.1 million in the years ended December 31, 2021 and 2020, related to the investment in these equity securities.
The gains related to equity securities are reported on the line Gain on equity securities in the "Other (income) expense" section
of the Consolidated Statements of Operations.
There were no transfers into or out of Levels 1, 2 or 3 during the year ended December 31, 2021.
Nonrecurring Fair Value Measurements: The Company regularly performs reviews of potential future development projects
and identified certain undeveloped properties where market conditions related to any future development deteriorated during
2020. As a result, the Company estimated the fair value of the assets using unobservable inputs, which are classified as Level 3
inputs. The long-lived assets were written down to their estimated fair value, which resulted in a non-cash asset impairment
charge of $7.3 million in the Minerals Management segment and $1.1 million in the Coal Mining segment for certain
capitalized leasehold costs, prepaid royalties and other assets during 2020. The fair value of these long-lived assets was
determined to be zero as such assets were deemed to have no future economic benefit based on the Company's analysis using
market participant assumptions, and therefore no expected future cash flows. The impairment charges are reported on the line
Asset impairment charges in the Consolidated Statements of Operations.
Other Fair Value Measurement Disclosures: The carrying amounts of cash and cash equivalents, accounts receivable and
accounts payable approximate fair value due to the short-term maturities of these instruments. The fair values of revolving
credit agreements and long-term debt, excluding finance leases, were determined using current rates offered for similar
obligations taking into account subsidiary credit risk, which is Level 2 as defined in the fair value hierarchy. The fair value and
the book value of revolving credit agreements and long-term debt, excluding finance leases, was $20.5 million and $20.4
million, respectively, at December 31, 2021 and $45.2 million and $45.0 million, respectively, at December 31, 2020.
Financial instruments that potentially subject the Company to concentration of credit risk consist principally of accounts
receivable. Under its mining contracts, the Company recognizes revenue and a related receivable as coal or limestone is
delivered. These mining contracts provide for monthly settlements. The Company's significant credit concentration is
uncollateralized; however, historically minimal credit losses have been incurred. To further reduce credit risk associated with
accounts receivable, the Company performs periodic credit evaluations of its customers, but does not generally require advance
payments or collateral.
NOTE 10—Leases
The Company recognizes right-of-use assets (“ROU assets”) and lease liabilities for operating leases of real estate, mining and
other equipment that expire at various dates through 2031. The majority of the Company's leases are operating leases. See the
table below for further information on the Consolidated Balance Sheet. The Company's lease agreements do not contain lease
payments that depend on an index or a rate, as such, minimum lease payments do not include variable lease payments.
F-23
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
Leased assets and liabilities include the following:
Description
Assets
Operating
Finance
Liabilities
Current
Operating
Finance
Noncurrent
Operating
Finance
Location
DECEMBER 31
2021
DECEMBER 31
2020
Operating lease right-of-use assets
Property, plant and equipment, net (a)
Other current liabilities
Current maturities of long-term debt
Operating lease liabilities
Long-term debt
$
$
$
8,911 $
334
10,324
1,478
1,463 $
150
9,733 $
190
1,457
1,188
11,196
280
(a) Finance leased assets are recorded net of accumulated amortization of $0.3 million and $0.2 million as of December 31, 2021
and December 31, 2020, respectively.
The components of lease expense for the years ended December 31 are as follows:
Description
Location
2021
2020
Lease expense
Operating lease cost
Finance lease cost:
Selling, general and administrative expenses $
2,122 $
2,103
Amortization of leased assets Cost of sales
Interest on lease liabilities
Interest expense
Variable lease expense
Short-term lease expense
Total lease expense
Selling, general and administrative expenses
Selling, general and administrative expenses
$
220
31
571
1,176
4,120 $
164
19
588
260
3,134
Future minimum finance and operating lease payments were as follows at December 31, 2021:
2022
2023
2024
2025
2026
Subsequent to 2026
Total minimum lease payments
Amounts representing interest
Present value of net minimum lease payments
Finance
Leases
Operating
Leases
Total
$
$
2,342
2,181 $
161 $
1,832
1,705
127
1,724
1,661
63
1,476
1,469
7
1,501
1,501
—
6,451
6,451
—
14,968 $ 15,326
358
3,772
18
340 $ 11,196
F-24
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
As most of the Company's leases do not provide an implicit rate, the Company determines the incremental borrowing rate based
on the information available at the lease commencement date in determining the present value of lease payments. The Company
considers its credit rating and the current economic environment in determining this collateralized rate. The assumptions used in
accounting for ASC 842 for the years ended December 31 are as follows:
Lease term and discount rate
Weighted average remaining lease term (years)
Operating
Finance
Weighted average discount rate
Operating
Finance
2021
2020
8.38
2.44
7.08 %
4.16 %
8.92
1.38
7.00 %
4.11 %
The following table details cash paid for amounts included in the measurement of lease liabilities for the years ended
December 31:
Cash paid for amounts included in the measurement of lease liabilities
Operating cash flows from operating leases
Operating cash flows from finance leases
Financing cash flows from finance leases
$
2021
2020
2,260 $
31
275
2,223
19
623
NOTE 11—Contingencies
Various legal and regulatory proceedings and claims have been or may be asserted against NACCO and certain subsidiaries
relating to the conduct of their businesses. These proceedings and claims are incidental to the ordinary course of business of the
Company. Management believes that it has meritorious defenses and will vigorously defend the Company in these actions. Any
costs that management estimates will be paid as a result of these claims are accrued when the liability is considered probable
and the amount can be reasonably estimated. If a range of amounts can be reasonably estimated and no amount within the
range is a better estimate than any other amount, then the minimum of the range is accrued. The Company does not accrue
liabilities when the likelihood that the liability has been incurred is probable but the amount cannot be reasonably estimated or
when the liability is believed to be only reasonably possible or remote. For contingencies where an unfavorable outcome is
probable or reasonably possible and which are material, the Company discloses the nature of the contingency and, in some
circumstances, an estimate of the possible loss.
These matters are subject to inherent uncertainties, and unfavorable rulings could occur. If an unfavorable ruling were to occur,
there exists the possibility of an adverse impact on the Company’s financial position, results of operations and cash flows of the
period in which the ruling occurs, or in future periods.
NOTE 12—Stockholders' Equity and Earnings Per Share
NACCO Industries, Inc. Class A common stock is traded on the New York Stock Exchange under the ticker symbol “NC.”
Because of transfer restrictions on Class B common stock, no trading market has developed, or is expected to develop, for the
Company's Class B common stock. The Class B common stock is convertible into Class A common stock on a one-for-one
basis at any time at the request of the holder. The Company's Class A common stock and Class B common stock have the same
cash dividend rights per share. As the liquidation and dividend rights are identical, any distribution of earnings would be
allocated to Class A and Class B stockholders on a proportionate basis, and accordingly the net income per share for each class
of common stock is identical. The Class A common stock has one vote per share and the Class B common stock has ten votes
per share. The total number of authorized shares of Class A common stock and Class B common stock at December 31, 2021
was 25,000,000 shares and 6,756,176 shares, respectively. Treasury shares of Class A common stock totaling 2,600,661 and
2,726,017 at December 31, 2021 and 2020, respectively, have been deducted from shares outstanding.
F-25
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
Stock Repurchase Programs: On November 10, 2021, the Company's Board of Directors approved a stock purchase program
("2021 Stock Repurchase Program") providing for the purchase of up to $20.0 million of the Company’s outstanding Class A
common stock through December 31, 2023. NACCO’s previous repurchase program ("2019 Stock Repurchase Program")
would have expired on December 31, 2021 but was terminated and replaced by the 2021 Stock Repurchase Program. The
Company repurchased 32,286 shares of Class A common stock under the 2019 Stock Repurchase Program for an aggregate
purchase price of $1.0 million during 2020.
The timing and amount of any repurchases under the 2021 Stock Repurchase Program are determined at the discretion of the
Company's management based on a number of factors, including the availability of capital, other capital allocation alternatives,
market conditions for the Company's Class A common stock and other legal and contractual restrictions. The 2021 Stock
Repurchase Program does not require the Company to acquire any specific number of shares and may be modified, suspended,
extended or terminated by the Company without prior notice and may be executed through open market purchases, privately
negotiated transactions or otherwise. All or part of the repurchases under the 2021 Stock Repurchase Program may be
implemented under a Rule 10b5-1 trading plan, which would allow repurchases under pre-set terms at times when the Company
might otherwise be restricted from doing so under applicable securities laws.
Stock Compensation: See Note 2 for a discussion of the Company's restricted stock awards.
Earnings per Share: The weighted average number of shares of Class A common stock and Class B common stock
outstanding used to calculate basic and diluted earnings per share were as follows:
Basic weighted average shares outstanding
Dilutive effect of restricted stock awards
Diluted weighted average shares outstanding
Basic earnings per share
Diluted earnings per share
2021
2020
7,146
44
7,190
$
$
6.73 $
6.69 $
7,026
31
7,057
2.11
2.10
F-26
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
NOTE 13—Income Taxes
The Company provides for income taxes and the related accounts under the asset and liability method. Deferred tax assets and
liabilities are determined based on the difference between the financial statement and tax bases of assets and liabilities using
enacted tax rates expected to be in effect during the year in which the basis differences reverse. Valuation allowances are
established when management determines it is more likely than not that some portion, or all, of the deferred tax assets will not
be realized.
The components of income (loss) before income tax provision (benefit) and the income tax provision (benefit) for the years
ended December 31 are as follows:
Income (loss) before income tax provision (benefit)
Domestic
Foreign
Income tax provision (benefit)
Current income tax provision (benefit):
Federal
State
Foreign
Total current
Deferred income tax (benefit) provision:
Federal
State
Total deferred
2021
2020
57,019 $
(169)
56,850 $
13,990
268
14,258
10,870 $
1,443
(35)
12,278
(4,449)
896
(3,553)
8,725 $
(7,859)
(408)
215
(8,052)
7,847
(330)
7,517
(535)
$
$
$
$
The Company made income tax payments of $11.5 million and $0.4 million during 2021 and 2020, respectively. During the
same periods, income tax refunds totaled $2.6 million and $4.2 million, respectively.
F-27
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
The provision for income taxes differs from the amount computed by applying the statutory federal income tax rate to income
before the provision for income taxes. A reconciliation of the federal statutory and effective income tax rate for the years ended
December 31 is as follows:
Income before income tax provision
Statutory taxes at 21.0%
State and local income taxes
Non-deductible expenses
Percentage depletion
R&D and other federal credits
Settlements and uncertain tax positions
Coronavirus Aid, Relief, and Economic Security ("CARES") Act - carryback rate
differential
Other, net
Income tax provision
Effective income tax rate
2021
2020
$ 56,850
$ 14,258
$ 11,939
1,890
725
(6,245)
(363)
166
—
613
8,725
$
$
$
2,994
(626)
426
(3,744)
(367)
6,286
(4,741)
(763)
(535)
15.3 %
(3.8) %
The Company recorded an income tax expense of $8.7 million for the year ended December 31, 2021 on income before income
tax of $56.9 million, or 15.3%, compared to income tax benefit of $0.5 million on income before income tax of $14.3 million,
or (3.8%), for the year ended December 31, 2020. The year ended December 31, 2020 includes $7.3 million of discrete tax
charges primarily related to settlement of tax examinations, reserves for uncertain tax positions and return to provision
adjustments partially offset by a benefit of $4.7 million, primarily due to the rate differential related to carrying back losses
under the provisions of the Coronavirus Aid, Relief, and Economic Security Act ("CARES Act"). The CARES Act allows net
operating tax losses incurred in 2018, 2019, and 2020 to be carried back to each of the five preceding taxable years to generate
a refund of previously paid income taxes. The Company generated a net tax operating loss in 2020 primarily due to the
realization of certain deferred tax assets. There were no material discrete items affecting income tax expense in 2021.
The effective income tax rate for 2021 reflects the impact of higher pre-tax income in 2021 compared with 2020, including the
termination fee associated with the Bisti contract termination. The effective income tax rate varies based upon the mix and
timing of earnings between entities that benefit from percentage depletion and those that do not benefit from percentage
depletion. The benefit from percentage depletion is not directly related to the amount of pre-tax income recorded in a period.
F-28
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
A detailed summary of the total deferred tax assets and liabilities in the Company's Consolidated Balance Sheets resulting from
differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for
income tax purposes is as follows:
Deferred tax assets
Lease liabilities
Tax carryforwards
Inventories
Accrued liabilities
Employee benefits
Land valuation adjustment
Other
Total deferred tax assets
Less: Valuation allowance
Deferred tax liabilities
Lease right-of-use assets
Depreciation and depletion
Partnership investment - development costs
Accrued pension benefits
Total deferred tax liabilities
Net deferred liability
December 31
2021
2020
$
24,500 $
13,837
4,522
9,243
3,496
5,988
6,527
68,113
11,695
56,418
24,500
25,851
9,840
10,941
71,132
27,800
17,756
3,742
10,160
2,747
5,536
5,401
73,142
11,549
61,593
27,800
31,972
11,686
7,685
79,143
$
(14,714) $
(17,550)
The following table summarizes the tax carryforwards and associated carryforward periods and related valuation allowances
where the Company has determined that realization is uncertain:
State net operating loss
State net operating loss
Federal research credit
Total
December 31, 2021
Net deferred tax
asset
Valuation
allowance
Carryforwards
expire during:
$
17,516 $
14,694
2022-2041
December 31, 2020
Net deferred tax
asset
Valuation
allowance
Carryforwards
expire during:
$
$
18,708 $
14,478
2021-2040
2,648
—
2034-2040
21,356 $
14,478
The Company has a valuation allowance for certain state and foreign deferred tax assets. Based upon the review of historical
earnings and the relevant expiration of carryforwards, including utilization limitations in the various state taxing jurisdictions,
the Company believes the valuation allowances are appropriate and does not expect to release valuation allowances within the
next twelve months that would have a significant effect on the Company's financial position or results of operations.
The tax returns of the Company and certain of its subsidiaries are under routine examination by various taxing authorities. The
Company has not been informed of any material assessment for which an accrual has not been previously provided and the
Company would vigorously contest any material assessment. Management believes any potential adjustment would not
materially affect the Company's financial condition or results of operations.
F-29
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
In general, the Company operates in taxing jurisdictions that provide a statute of limitations period ranging from three to five
years for the taxing authorities to review the applicable tax filings. The examination of the 2013-2016 U.S. federal tax returns is
ongoing. The Company has extended the statute of limitations to allow the U.S. taxing authorities to complete their
examination.
The following is a reconciliation of the Company's total gross unrecognized tax benefits, defined as the aggregate tax effect of
differences between tax return positions and the benefits recognized in the financial statements for the years ended
December 31, 2021 and 2020. The increase in the gross unrecognized tax benefits in 2020 was primarily due to tax positions
related to worthlessness losses for which the timing of deductibility is uncertain. Approximately $6.4 million and $6.3 million
of the gross unrecognized tax benefits as of December 31, 2021 and 2020, respectively, relate to permanent items that, if
recognized, would impact the effective income tax rate. This amount differs from the gross unrecognized tax benefits presented
in the table below due to (1) the deferred tax asset which would be available if the position were not sustained upon audit and
(2) the decrease in U.S. federal income taxes which would occur upon the recognition of the state tax benefits included herein.
Balance at January 1
Additions based on tax positions related to prior years
Decreases based on settlements with tax authorities
Additions based on tax positions related to the current year
Balance at December 31
2021
2020
$
10,459 $
95
—
—
$
10,554 $
2,860
2,774
(803)
5,628
10,459
The Company records interest and penalties on uncertain tax positions as a component of the income tax provision. The
Company recognized net expense of less than $0.1 million and net benefit of less than $0.1 million in interest and penalties
related to uncertain tax positions during 2021 and 2020, respectively. The total amount of interest and penalties accrued was
$0.2 million and $0.1 million as of December 31, 2021 and 2020, respectively.
The Company expects the amount of unrecognized tax benefits will change within the next 12 months; however, the change in
unrecognized tax benefits, which is reasonably possible within the next 12 months, is not expected to have a significant effect
on the Company's financial position, results of operations or cash flows.
NOTE 14—Retirement Benefit Plans
Defined Benefit Plans: The Company maintains defined benefit pension plans that provide benefits based on years of service
and average compensation during certain periods. Prior to 2020, the Company amended the Combined Defined Benefit Plan for
NACCO Industries, Inc. and its subsidiaries (the “Combined Plan”) to freeze pension benefits for all employees. The Company
also amended the Supplemental Retirement Benefit Plan (the “SERP”) to freeze all pension benefits. All eligible employees of
the Company, including employees whose pension benefits are frozen, receive retirement benefits under defined contribution
retirement plans.
F-30
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
The assumptions used in accounting for the defined benefit plans were as follows for the years ended December 31:
Weighted average discount rates for pension benefit obligation
Weighted average discount rates for net periodic benefit cost
Expected long-term rate of return on assets for net periodic benefit cost
2021
2020
2.53% - 2.77% 2.02% - 2.36%
2.02% - 2.36% 2.98% - 3.20%
7.00 %
7.00 %
Set forth below is detail of the net periodic pension income for the defined benefit plans for the years ended December 31:
Interest cost
Expected return on plan assets
Amortization of actuarial loss
Amortization of prior service cost
Net periodic pension income
2021
2020
$
1,002 $
(2,568)
718
59
1,285
(2,435)
597
58
$
(789) $
(495)
Set forth below is detail of other changes in plan assets and benefit obligations recognized in other comprehensive (income)
loss for the years ended December 31:
Current year actuarial (gain) loss
Amortization of actuarial loss
Amortization of prior service cost
Total recognized in other comprehensive (income) loss
2021
2020
$
(3,793) $
(718)
(59)
$
(4,570) $
667
(597)
(58)
12
F-31
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
The following table sets forth the changes in the benefit obligation and the plan assets during the year and the funded status of
the defined benefit plans at December 31:
2021
2020
Change in benefit obligation
Projected benefit obligation at beginning of year
Interest cost
Actuarial (gain) loss
Benefits paid
Projected benefit obligation at end of year
Accumulated benefit obligation at end of year
Change in plan assets
Fair value of plan assets at beginning of year
Actual return on plan assets
Employer contributions
Benefits paid
Fair value of plan assets at end of year
Funded status at end of year
Amounts recognized in the balance sheets consist of:
Non-current assets
Current liabilities
Non-current liabilities
Components of accumulated other comprehensive loss consist of:
Actuarial loss
Prior service cost
Deferred taxes
$
$
$
$
$
$
$
$
$
$
44,600 $
1,002
(1,367)
(2,572)
41,663 $
41,663 $
41,099 $
4,995
487
(2,572)
44,009 $
2,346 $
7,806 $
(542)
(4,918)
2,346 $
9,510 $
703
(2,254)
7,959 $
41,854
1,285
3,996
(2,535)
44,600
44,600
37,364
5,763
507
(2,535)
41,099
(3,501)
4,070
(549)
(7,022)
(3,501)
14,022
761
(3,316)
11,467
The Company recognizes as a component of benefit (income) cost, as of the measurement date, any unrecognized actuarial net
gains or losses that exceed 10% of the larger of the projected benefit obligations or the plan assets, defined as the "corridor."
Amounts outside the corridor are amortized over the average expected remaining service of active participants expected to
benefit under the retiree medical plans or over the average expected remaining lifetime of inactive participants for the pension
plans. The (gain) loss amounts recognized in AOCI are not expected to be fully recognized until the plan is terminated or as
settlements occur, which would trigger accelerated recognition. Prior service costs resulting from plan changes are also in
AOCI.
The Company's policy is to make contributions to fund its pension plans within the range allowed by applicable regulations.
The Company maintains one supplemental defined benefit plan that pays monthly benefits to participants directly out of
corporate funds. All other pension benefit payments are made from assets of the pension plans.
F-32
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
Future pension benefit payments expected to be paid from assets of the pension plans are:
2022
2023
2024
2025
2026
2027 - 2031
$
$
2,710
2,697
2,716
2,684
2,672
12,779
26,258
The expected long-term rate of return on defined benefit plan assets reflects management's expectations of long-term rates of
return on funds invested to provide for benefits included in the projected benefit obligations. In establishing the expected long-
term rate of return assumption for plan assets, the Company considers the historical rates of return over a period of time that is
consistent with the long-term nature of the underlying obligations of these plans as well as a forward-looking rate of return. The
historical and forward-looking rates of return for each of the asset classes used to determine the Company's estimated rate of
return assumption were based upon the rates of return earned or expected to be earned by investments in the equivalent
benchmark market indices for each of the asset classes.
Expected returns for pension plans are based on a calculated market-related value for pension plan assets. Under this
methodology, asset gains and losses resulting from actual returns that differ from the Company's expected returns are
recognized in the market-related value of assets ratably over three years.
The pension plans maintain investment policies that, among other things, establish a portfolio asset allocation methodology
with percentage allocation bands for individual asset classes. The investment policies provide that investments are reallocated
between asset classes as balances exceed or fall below the appropriate allocation bands.
The following is the actual allocation percentage and target allocation percentage for the pension plan assets at December 31:
U.S. equity securities
Non-U.S. equity securities
Fixed income securities
Money market
2021
Actual
Allocation
2020
Actual
Allocation
Target Allocation
Range
48.7 %
19.7 %
31.2 %
0.4 %
45.4 % 36.0% - 54.0%
20.3 % 16.0% - 24.0%
33.9 % 30.0% - 40.0%
0.4 % 0.0% - 10.0%
The defined benefit pension plans do not have any direct ownership of NACCO common stock.
The fair value of each major category of the Company's pension plan assets are valued using quoted market prices in active
markets for identical assets, or Level 1 in the fair value hierarchy. Following are the values as of December 31:
U.S. equity securities
Non-U.S. equity securities
Fixed income securities
Money market
Total
Level 1
2021
2020
$
21,434 $
18,640
8,678
13,723
174
8,335
13,948
176
$
44,009 $
41,099
Postretirement Health Care: The Company also maintains health care plans which provide benefits to grandfathered eligible
retired employees. All health care plans of the Company have a cap on the Company's share of the costs. The health care plans
have network provided benefits which result in cost savings for the Company. These plans have no assets. Under the
Company's current policy, plan benefits are funded at the time they are due to participants.
F-33
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
The assumptions used in accounting for the postretirement health care plans are set forth below for the years ended
December 31:
Weighted average discount rates for benefit obligation
Weighted average discount rates for net periodic benefit cost
Health care cost trend rate assumed for next year
Rate to which the cost trend rate is assumed to decline (ultimate trend rate)
Year that the rate reaches the ultimate trend rate
2021
2020
2.12 %
1.37 %
1.37 % 1.37% - 2.65%
6.50 %
6.25 %
4.50 %
2029
5.00 %
2027
Set forth below is detail of the net periodic benefit expense (income) for the postretirement health care plans for the years ended
December 31:
Service cost
Interest cost
Amortization of actuarial loss (gain)
Amortization of prior service credit
Amortization of curtailment
Net periodic benefit expense (income)
2021
2020
$
13 $
27
19
(54)
—
5 $
$
21
52
(1)
(59)
(31)
(18)
Set forth below is detail of other changes in plan assets and benefit obligations recognized in other comprehensive loss for the
years ended December 31:
Current year actuarial (gain) loss
Amortization of actuarial (loss) gain
Amortization of prior service credit
Amortization of curtailment
Transfers
$
2021
2020
(48) $
(19)
54
—
126
194
1
59
31
46
Total recognized in other comprehensive loss
$
113 $
331
F-34
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
The following sets forth the changes in benefit obligations during the year and the funded status of the postretirement health
care at December 31:
Change in benefit obligation
Benefit obligation at beginning of year
Service cost
Interest cost
Plan amendments
Actuarial (gain) loss
Benefits paid
Benefit obligation at end of year
Funded status at end of year
Amounts recognized in the balance sheets consist of:
Current liabilities
Noncurrent liabilities
Components of accumulated other comprehensive loss consist of:
Actuarial loss
Prior service credit
Deferred taxes
Future postretirement health care benefit payments expected to be paid are:
2022
2023
2024
2025
2026
2027 - 2031
2021
2020
$
2,054 $
2,049
$
$
$
$
$
$
13
27
—
(48)
(169)
1,877 $
(1,877) $
(190) $
(1,687)
(1,877) $
520 $
(108)
(195)
217 $
$
21
52
49
145
(262)
2,054
(2,054)
(238)
(1,816)
(2,054)
466
(167)
(167)
132
191
191
182
176
169
700
1,609
Defined Contribution Plans: NACCO and its subsidiaries maintain a defined contribution (401(k)) plan for substantially all
employees and provide employer matching contributions based on plan provisions. The plan also provides for a minimum
employer contribution. Total costs, including Company contributions, for these plans were $2.9 million and $2.8 million in
2021 and 2020, respectively.
NOTE 15—Business Segments
The Company’s operating segments are: (i) Coal Mining, (ii) NAMining and (iii) Minerals Management. The Company
determines its reportable segments by first identifying its operating segments, and then by assessing whether any components of
these segments constitute a business for which discrete financial information is available and where segment management
regularly reviews the operating results of that component. The Company’s Chief Operating Decision Maker utilizes operating
profit to evaluate segment performance and allocate resources.
The Company has items not directly attributable to a reportable segment which are not included as part of the measurement of
segment operating profit, which are primarily administrative costs related to public company reporting requirements at the
parent company and the financial results of Mitigation Resources and Bellaire. Mitigation Resources generates and sells stream
F-35
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
and wetland mitigation credits (known as mitigation banking) and provides services to those engaged in permittee-responsible
stream and wetland mitigation. Bellaire manages the Company’s long-term liabilities related to former Eastern U.S.
underground mining activities.
All financial statement line items below operating profit (other income including interest expense and interest income, the
provision for income taxes and net income) are presented and discussed within this Form 10-K on a consolidated basis.
See Note 1 for additional discussion of the Company's reportable segments. All current operations reside in the U.S. The
accounting policies of the reportable segments are described in Note 2 and Note 20.
In 2021 and 2020, two customers individually accounted for more than 10% of consolidated revenue. The following represents
the revenue attributable to each of these entities as a percentage of consolidated revenue for those years:
Segment
Coal Mining customer
NAMining customer
Percentage of Consolidated
Revenue
2021
2020
43 %
19 %
55 %
19 %
In addition, for the year ended December 31, 2021, the Coal Mining segment derived approximately 68% of the Earnings of
Unconsolidated Operations from two customers, Basin Electric and GRE.
F-36
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
The following tables present revenue, operating profit, depreciation expense and capital expenditures for the years ended
December 31:
Revenues
Coal Mining
NAMining
Minerals Management
Unallocated Items
Eliminations
Total
Operating profit (loss)
Coal Mining
NAMining
Minerals Management
Unallocated Items
Eliminations
Total
Expenditures for property, plant and equipment and acquisition of mineral interests
Coal Mining
NAMining
Minerals Management
Unallocated Items
Total
Depreciation, depletion and amortization
Coal Mining
NAMining
Minerals Management
Unallocated Items
Total
2021
2020
$
91,851 $
69,924
31,003
4,695
72,088
42,392
14,721
2,133
(5,627)
(2,902)
$
191,846 $
128,432
$
49,059 $
25,436
109
26,080
1,872
3,493
(19,553)
(17,256)
(285)
(97)
$
55,410 $
13,448
$
16,830 $
21,100
6,423
208
14,825
13,862
15,474
207
$
44,561 $
44,368
$
$
16,649 $
4,435
1,858
143
23,085 $
14,213
2,470
1,308
123
18,114
Asset information by segment is not discretely maintained for internal reporting or used in evaluating performance.
F-37
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
NOTE 16—Parent Company Condensed Balance Sheets
The condensed balance sheets of NACCO, the parent company, at December 31 are as follows:
ASSETS
Cash and cash equivalents
Accounts receivable from affiliates
Other current assets
Investment in subsidiaries
Property, plant and equipment, net
Other non-current assets
Total Assets
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities
Current intercompany accounts payable, net
Note payable to Bellaire
Other non-current liabilities
Stockholders’ equity
$
$
$
2021
2020
83,093 $
—
17,578
268,720
57
4,885
85,365
495
20,648
211,468
110
5,890
374,333 $
323,976
3,865 $
637
16,750
965
352,116
3,242
2,337
16,750
1,023
300,624
323,976
Total Liabilities and Stockholders’ Equity
$
374,333 $
The credit agreement at NACoal allows for the transfer of assets to NACCO under certain circumstances. The amount of
NACCO's investment that was restricted at December 31, 2021 totaled approximately $1.8 million. The amount of unrestricted
cash available to NACCO included in “Investment in subsidiaries” was $1.2 million at December 31, 2021. Dividends and
management fees from its subsidiaries are the primary sources of cash for NACCO.
NOTE 17—Unconsolidated Subsidiaries
Each of the Company's wholly owned Unconsolidated Subsidiaries, within the Coal Mining and NAMining segments, meet the
definition of a VIE. The Unconsolidated Subsidiaries are capitalized primarily with debt financing provided by or supported by
their respective customers, and generally without recourse to NACCO and NACoal. Although NACoal owns 100% of the
equity and manages the daily operations of the Unconsolidated Subsidiaries, the Company has determined that the equity
capital provided by NACoal is not sufficient to adequately finance the ongoing activities or absorb any expected losses without
additional support from the customers. The customers have a controlling financial interest and have the power to direct the
activities that most significantly affect the economic performance of the entities. As a result, the Company is not the primary
beneficiary and therefore does not consolidate these entities' financial positions or results of operations. See Note 1 for a
discussion of these entities.
The investment in the unconsolidated subsidiaries and related tax positions totaled $19.1 million and $29.0 million at
December 31, 2021 and 2020, respectively. The Company's risk of loss relating to these entities is limited to its invested capital,
which was $7.6 million and $6.5 million at December 31, 2021 and 2020, respectively.
NACoal is a party to certain guarantees related to Coyote Creek. Under certain circumstances of default or termination of
Coyote Creek’s Lignite Sales Agreement (“LSA”), NACoal would be obligated for payment of a "make-whole" amount to
Coyote Creek’s third-party lenders. The “make-whole” amount is based on the excess, if any, of the discounted value of the
remaining scheduled debt payments over the principal amount. In addition, in the event Coyote Creek’s LSA is terminated on
or after January 1, 2024 by Coyote Creek’s customers, NACoal is obligated to purchase Coyote Creek’s dragline and rolling
stock for the then net book value of those assets. To date, no payments have been required from NACoal since the inception of
these guarantees. The Company believes that the likelihood NACoal would be required to perform under the guarantees is
remote, and no amounts related to these guarantees have been recorded.
F-38
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
Summarized financial information for the unconsolidated subsidiaries is as follows:
Statement of Operations
Revenue
Gross profit
Income before income taxes
Net income
Balance Sheet
Current assets
Non-current assets
Current liabilities
Non-current liabilities
2021
2020
$
$
$
$
$
$
$
$
764,759 $
768,660
68,076 $
60,865 $
53,248 $
69,021
60,398
50,933
168,669 $
186,934
900,924 $
959,032
98,887 $
143,843
963,128 $
995,658
Revenue includes all mine operating costs that are reimbursed by the customers of the Unconsolidated Subsidiaries as well as
the compensation per ton of coal, heating unit (MMBtu) or ton of limestone delivered. Reimbursed costs have offsetting
expenses and have no impact on income before income taxes. Income before income taxes represents the Earnings of the
unconsolidated operations and the Income from other unconsolidated affiliates.
NACoal received dividends of $51.7 million and $49.7 million from the Unconsolidated Subsidiaries in 2021 and 2020,
respectively.
NOTE 18—Related Party Transactions
One of the Company's directors is a retired Jones Day partner. Legal services rendered by Jones Day approximated $1.2 million
and $1.0 million for the years ended December 31, 2021 and 2020.
Alfred M. Rankin, Jr. continues to serve as the Chairman of the Board of Directors of NACCO and Mr. Rankin supports the
President and Chief Executive Officer of NACCO upon request under the terms of a consulting agreement. Fees for consulting
services rendered by Mr. Rankin approximated $0.5 million for both of the years ended December 31, 2021 and 2020.
Hyster-Yale Materials Handling, Inc. ("Hyster-Yale") is a former subsidiary of the Company that was spun-off to stockholders
in 2012. Mr. Rankin is Chairman, President and Chief Executive Officer of Hyster-Yale Materials Handling and Chairman,
Hyster-Yale Group. In the ordinary course of business, NACoal leases or buys Hyster-Yale lift trucks. The terms may not be
comparable to terms that would be obtained in a transaction between unaffiliated parties.
NOTE 19—Other Events and Transactions
Voluntary Separation Program: During the fourth quarter of 2020, the Company adopted a voluntary separation program
("2020 VSP") for eligible employees who met certain age and service requirements in an effort to reduce overall headcount at
the Company’s headquarters. The irrevocable acceptance period for associates electing to participate in the 2020 VSP ended
during December 2020. In the fourth quarter of 2020, the Company recorded pre-tax charges for the 2020 VSP of $1.8 million
included in Selling, general and administrative expense in the accompanying Consolidated Statements of Operations.
NOTE 20—Supplemental Oil and Gas Disclosures (Unaudited)
The Minerals Management segment derives income primarily by leasing its royalty and mineral interests to third-party
exploration and production companies, and, to a lesser extent, other mining companies, granting them the rights to explore,
develop, mine, produce, market and sell gas, oil, and coal in exchange for royalty payments based on the lessees' sales of those
minerals. As an owner of royalty and mineral interests, the Company’s access to information concerning activity and operations
of its royalty and mineral interests is limited. The Company does not have information that would be available to a company
with working interests in oil and natural gas operations because detailed information is not generally available to owners of
royalty and mineral interests. See Note 1, Note 2 and Note 15 for additional discussion of the Minerals Management segment.
F-39
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
During 2021 and 2020, the Minerals Management segment acquired additional mineral interests, primarily in the Eagle Ford
and Permian Basins in Texas. Total consideration for the 2021 and 2020 acquisitions of mineral and royalty interests was
$5.3 million and $14.2 million, respectively. The 2021 acquisitions include 20.6 thousand gross acres and 1.8 thousand net
royalty acres. The 2020 acquisitions include 65.5 thousand gross acres and 1.2 thousand net royalty acres. Total oil and gas
mineral and royalty interests include approximately 127.8 thousand gross acres and 59.9 thousand net royalty acres at
December 31, 2021.
Aggregate capitalized costs related to oil and gas royalty and mineral interests with applicable accumulated depreciation,
depletion and amortization at December 31 are as follows:
Proved developed
Proved undeveloped
Less: accumulated depreciation, depletion and amortization
Net royalty interests in oil and natural gas properties
2021
3,266
16,246
868
18,644
$
$
Total net proved reserves are defined as those natural gas and hydrocarbon liquid reserves to Company interests after deducting
all royalties, overriding royalties, and reversionary interests owned by outside parties that become effective upon payout of
specified monetary balances. Decline curve analysis was used to estimate the remaining reserves of pressure depletion
reservoirs with enough historical production data to establish decline trends. Reservoirs under non-pressure depletion drive
mechanisms and non-producing reserves were estimated by volumetric analysis, research of analogous reservoirs, or a
combination of both. Reserves have been estimated using deterministic and probabilistic methods. All reserves estimates have
been prepared using standard engineering practices generally accepted by the petroleum industry and conform to guidelines
developed and adopted by the SEC.
The following table presents the Company's estimated net proved oil and natural gas reserves as of December 31, 2021 based
on the reserve report prepared by Haas Engineering, the Company’s independent petroleum engineering firm. All of the
Company’s reserves are located in the United States.
Proved developed
Proved undeveloped
Total
Oil (bbl) (1)
Net reserves as of December 31, 2021
NGL (bbl) (1)
Residue gas (Mcf) (2)
167,430
220
167,650
282,230
90
282,320
16,617,360
1,210
16,618,570
(1) Bbl. One stock tank barrel, or 42 U.S. gallons liquid volume.
(2) Mcf. One thousand cubic feet of natural gas at the contractual pressure and temperature bases.
Standardized Measure of Discounted Future Net Cash Flows
Future cash inflows represent expected revenues from production of period-end quantities of proved reserves based on the 12-
month unweighted average of first-day-of-the-month commodity prices for the periods presented. Future cash inflows are
computed by applying applicable prices relating to proved reserves to the year-end quantities of those reserves. Future
production and costs are derived based on current costs assuming continuation of existing economic conditions. Federal income
tax expenses are deducted from future production revenues in the calculation of the standardized measure using the statutory tax
rate. The Company is subject to certain state based taxes; however, these amounts are not material. The projections should not
be viewed as realistic estimates of future cash flows, nor should the “standardized measure” be interpreted as representing
current value to the Company. Material revisions to estimates of proved reserves may occur in the future; development and
production of the reserves may not occur in the periods assumed; actual prices realized are expected to vary significantly from
those used; and actual costs may vary.
F-40
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
The following table provides the future net cash flows relating to proved oil and gas reserves based on the standardized measure
of discounted cash flows as of December 31, 2021:
Gross Amounts
Statutory tax rate
Net Amounts
Future cash inflows
Future production costs
$
Future net cash flows before income tax expense
10% discount to reflect timing of cash flows
Standardized measure of discounted cash flows
$
71,400
14,664
56,736
(19,897)
36,839
21 %
21 %
21 % $
44,821
(15,719)
29,102
F-41
Table of Contents
SCHEDULE I—CONDENSED FINANCIAL INFORMATION OF THE PARENT
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
PARENT COMPANY CONDENSED BALANCE SHEETS
ASSETS
Cash and cash equivalents
Accounts receivable from affiliates
Other current assets
Investment in subsidiaries
Property, plant and equipment, net
Other non-current assets
Total Assets
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities
Current intercompany accounts payable, net
Note payable to Bellaire
Other non-current liabilities
Stockholders’ equity
December 31
2021
2020
(In thousands)
$
83,093 $
—
17,578
268,720
57
4,885
85,365
495
20,648
211,468
110
5,890
374,333 $
323,976
$
$
3,865 $
637
16,750
965
352,116
3,242
2,337
16,750
1,023
300,624
323,976
Total Liabilities and Stockholders’ Equity
$
374,333 $
See Notes to Parent Company Condensed Financial Statements.
F-42
SCHEDULE I—CONDENSED FINANCIAL INFORMATION OF THE PARENT
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
PARENT COMPANY CONDENSED STATEMENTS OF COMPREHENSIVE INCOME
Expense (income):
Intercompany interest expense
Other, net
Administrative and general expenses
Loss before income taxes
Income tax (benefit) provision
Net loss before equity in earnings of subsidiaries
Equity in earnings of subsidiaries
Net income
Current period pension and postretirement plan adjustment, net of $864 tax expense and $213
tax benefit in 2021 and 2020, respectively
Reclassification of pension and postretirement adjustments into earnings, net of $170 and $129
tax benefit in 2021 and 2020, respectively
Total other comprehensive income
Comprehensive Income
See Notes to Parent Company Condensed Financial Statements.
Year Ended December 31
2021
2020
(In thousands)
$
1,172 $
(336)
836
4,300
(5,136)
(463)
(4,673)
52,798
48,125
2,851
572
3,423
1,178
(1,003)
175
5,658
(5,833)
2,419
(8,252)
23,045
14,793
(697)
435
(262)
$
51,548 $
14,531
F-43
SCHEDULE I—CONDENSED FINANCIAL INFORMATION OF THE PARENT
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
PARENT COMPANY CONDENSED STATEMENTS OF CASH FLOWS
Operating Activities
Net income
Equity in earnings of subsidiaries
Parent company only net loss
Net changes related to operating activities
Net cash provided by (used for) operating activities
Investing Activities
Net cash used for investing activities
Financing Activities
Dividends received from subsidiaries
Notes payable to Bellaire
Purchase of treasury shares
Cash dividends paid
Net cash used for financing activities
Cash and cash equivalents
Decrease for the period
Balance at the beginning of the period
Balance at the end of the period
See Notes to Parent Company Condensed Financial Statements.
Year Ended December 31
2021
2020
(In thousands)
$
48,125 $
52,798
(4,673)
8,018
3,345
—
—
—
—
(5,617)
(5,617)
14,793
23,045
(8,252)
(22,822)
(31,074)
—
3,000
(200)
(1,002)
(5,375)
(3,577)
(2,272)
(34,651)
85,365
120,016
$
83,093 $
85,365
F-44
SCHEDULE I—CONDENSED FINANCIAL INFORMATION OF THE PARENT
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
NOTES TO PARENT COMPANY CONDENSED FINANCIAL STATEMENTS
FOR THE YEAR ENDED DECEMBER 31, 2021 AND 2020
The notes to Consolidated Financial Statements, incorporated in Item 15 of this Form 10-K, are hereby incorporated by
reference into these Notes to Parent Company Condensed Financial Statements.
NOTE A — ACCOUNTING POLICIES
In the Parent Company Condensed Financial Statements, NACCO's investment in subsidiaries is stated at cost plus equity in
undistributed earnings of subsidiaries since the date of acquisition. NACCO's share of net income of unconsolidated
subsidiaries is included in net income using the equity method. Parent Company financial statements should be read in
conjunction with the Company's consolidated financial statements.
NOTE B — LONG-TERM OBLIGATIONS AND GUARANTEES
It is NACCO's policy not to guarantee the debt of NACoal.
NOTE C — UNRESTRICTED CASH
The amount of unrestricted cash available to NACCO, included in Investment in subsidiaries, was $1.2 million at December 31,
2021 and was in addition to the $83.1 million of cash included in the Parent Company Condensed Balance Sheet at
December 31, 2021.
F-45
SCHEDULE II—VALUATION AND QUALIFYING ACCOUNTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
YEAR ENDED DECEMBER 31, 2021 AND 2020
Description
2021
Reserves deducted from asset accounts:
Additions
Balance at
Beginning
of Period
Charged to
Costs and
Expenses
Charged to
Other
Accounts
— Describe
Deductions
— Describe
Balance at
End of
Period (A)
(In thousands)
Deferred tax valuation allowances
$ 11,549 $
146 $
— $ —
$ 11,695
2020
Reserves deducted from asset accounts:
Deferred tax valuation allowances
$ 12,296 $
(747) $
— $ —
$ 11,549
(A)
Balances which are not required to be presented and those which are immaterial have been omitted.
F-46
The following is a list of active subsidiaries as of the date of the filing with the Securities and Exchange Commission of the
Annual Report on Form 10‑K to which this is an Exhibit. Except as noted, all of these subsidiaries are wholly owned, directly
or indirectly.
SUBSIDIARIES OF NACCO INDUSTRIES, INC.
Exhibit 21
Name
America Lignite Energy LLC
Bellaire Corporation
C&H Mining Company, Inc.
Caddo Creek Resources Company, LLC
Camino Real Fuels, LLC
Catapult Mineral Partners, LLC
Centennial Natural Resources, LLC
Coyote Creek Mining Company, LLC
Demery Resources Company, LLC
The Coteau Properties Company
The Falkirk Mining Company
GRENAC, LLC
Liberty Fuels Company, LLC
Mississippi Lignite Mining Company
Mitigation Resources of North America, LLC
Mitigate Alabama, LLC
Mitigate Tennessee, LLC
Mitigate Texas, LLC
NAM - CMX, LLC
NAM - Corkscrew, LLC
NAM - CSA, LLC
NAM - IND, LLC
NAM - Little River, LLC
NAM - MCA, LLC
NAM - Newberry, LLC
NAM - PBA, LLC
NAM - Pasco, LLC
NAM - Perry, LLC
NAM - QueenField, LLC
NAM - Rosser, LLC
NAM - SACC, LLC
NAM - SDI, LLC
NAM - WFA, LLC
NAM - WRQ, LLC
NAM - 7D, LLC
NoDak Energy Investments Corporation
The North American Coal Corporation
North American Coal Corporation India Private Limited
North American Mining, LLC
North American Coal Royalty Company
Otter Creek Mining Company LLC
Red Hills Property Company LLC
The Sabine Mining Company
Sawtooth Mining, LLC
Trident Technology Services Group, LLC
Trifecta Renewable Solutions, LLC
TRU Global Energy Services, LLC
TRU Energy Services, LLC
Reed Minerals, Inc.
Yockanookany Mitigation Resources, LLC
Incorporation
Delaware (50%)
Ohio
Alabama
Nevada
Nevada
Nevada
Nevada
Nevada
Nevada
Ohio
Ohio
Delaware (50%)
Nevada
Texas
Nevada
Nevada
Nevada
Nevada
Nevada
Nevada
Nevada
Nevada
Nevada
Nevada
Nevada
Nevada
Nevada
Nevada
Nevada
Nevada
Nevada
Nevada
Nevada
Nevada
Nevada
Nevada
Delaware
India
Nevada
Delaware
Nevada
Mississippi
Nevada
Nevada
Nevada
Delaware
Delaware
Nevada
Alabama
Nevada
I, J.C. Butler, Jr., certify that:
Certifications
Exhibit 31(i)(1)
1.
2.
3.
4.
I have reviewed this annual report on Form 10-K of NACCO Industries, Inc.;
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a
material fact necessary to make the statements made, in light of the circumstances under which such
statements were made, not misleading with respect to the period covered by this report;
Based on my knowledge, the financial statements, and other financial information included in this report,
fairly present in all material respects the financial condition, results of operations and cash flows of the
registrant as of, and for, the periods presented in this report;
The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure
controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over
financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
a)
b)
c)
d)
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures
to be designed under our supervision, to ensure that material information relating to the registrant,
including its consolidated subsidiaries, is made known to us by others within those entities,
particularly during the period in which this report is being prepared;
Designed such internal control over financial reporting, or caused such internal control over financial
reporting to be designed under our supervision, 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;
Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in
this report our conclusions about the effectiveness of the disclosure controls and procedures, as of
the end of the period covered by this report based on such evaluation; and
Disclosed in this report any change in the registrant’s internal control over financial reporting that
occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the
case of an annual report) that has materially affected, or is reasonably likely to materially affect, the
registrant’s internal control over financial reporting; and
5.
The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of
internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s
board of directors (or persons performing the equivalent functions):
a)
b)
All significant deficiencies and material weaknesses in the design or operation of internal control
over financial reporting which are reasonably likely to adversely affect the registrant’s ability to
record, process, summarize and report financial information; and
Any fraud, whether or not material, that involves management or other employees who have a
significant role in the registrant’s internal control over financial reporting.
Date: March 2, 2022
/s/ J.C. Butler, Jr.
J.C. Butler, Jr.
President and Chief Executive Officer
I, Elizabeth I. Loveman, certify that:
Certifications
Exhibit 31(i)(2)
1.
2.
3.
4.
I have reviewed this annual report on Form 10-K of NACCO Industries, Inc.;
Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a
material fact necessary to make the statements made, in light of the circumstances under which such
statements were made, not misleading with respect to the period covered by this report;
Based on my knowledge, the financial statements, and other financial information included in this report,
fairly present in all material respects the financial condition, results of operations and cash flows of the
registrant as of, and for, the periods presented in this report;
The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure
controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over
financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:
a)
b)
c)
d)
Designed such disclosure controls and procedures, or caused such disclosure controls and procedures
to be designed under our supervision, to ensure that material information relating to the registrant,
including its consolidated subsidiaries, is made known to us by others within those entities,
particularly during the period in which this report is being prepared;
Designed such internal control over financial reporting, or caused such internal control over financial
reporting to be designed under our supervision, 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;
Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in
this report our conclusions about the effectiveness of the disclosure controls and procedures, as of
the end of the period covered by this report based on such evaluation; and
Disclosed in this report any change in the registrant’s internal control over financial reporting that
occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the
case of an annual report) that has materially affected , or is reasonably likely to materially affect, the
registrant’s internal control over financial reporting; and
5.
The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of
internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s
board of directors (or persons performing the equivalent functions):
a)
b)
All significant deficiencies and material weaknesses in the design or operation of internal control
over financial reporting which are reasonably likely to adversely affect the registrant’s ability to
record, process, summarize and report financial information; and
Any fraud, whether or not material, that involves management or other employees who have a
significant role in the registrant’s internal control over financial reporting.
Date: March 2, 2022
/s/ Elizabeth I. Loveman
Elizabeth I. Loveman
Vice President and Controller
(principal financial officer)
Exhibit 32
CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO SECTION 906 OF
THE SARBANES-OXLEY ACT OF 2002
In connection with the Annual Report of NACCO Industries, Inc. (the “Company”) on Form 10-K for the year ended
December 31, 2021, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), each of the
undersigned officers of the Company certifies, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-
Oxley Act of 2002, that, to such officer's knowledge:
(1)
(2)
The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of
1934; and
The information contained in the Report fairly presents, in all material respects, the financial condition and
results of operations of the Company as of the dates and for the periods expressed in the Report.
Date: March 2, 2022
Date: March 2, 2022
/s/ J.C. Butler, Jr.
J.C. Butler, Jr.
President and Chief Executive Officer
/s/ Elizabeth I. Loveman
Elizabeth I. Loveman
Vice President and Controller
(principal financial officer)
MINE SAFETY DISCLOSURES
Exhibit 95
NACCO Industries, Inc. (the “Company”) believes that The North American Coal Corporation and its affiliated mining
companies (collectively, “NACoal”) is an industry leader in safety. NACoal has health and safety programs in place that
include extensive employee training, accident prevention, workplace inspection, emergency response, accident investigation,
regulatory compliance and program auditing. The objectives for NACoal's programs are to eliminate workplace incidents,
comply with all mining-related regulations and provide support for both regulators and the industry to improve mine safety.
Under the Dodd-Frank Wall Street Reform and Consumer Protection Act, each operator of a coal or other mine is required to
include certain mine safety results in its periodic reports filed with the Securities and Exchange Commission. The operation of
NACoal's mines is subject to regulation by the Federal Mine Safety and Health Administration ("MSHA") under the Federal
Mine Safety and Health Act of 1977 (the "Mine Act"). MSHA inspects NACoal's mines on a regular basis and issues various
citations and orders when it believes a violation has occurred under the Mine Act. The Company has presented information
below regarding certain mining safety and health matters for NACoal's mining operations for the year ended December 31,
2021. In evaluating this information, consideration should be given to factors such as: (i) the number of citations and orders will
vary depending on the size of the mine, (ii) the number of citations issued will vary from inspector to inspector and from mine
to mine, and (iii) citations and orders can be contested and appealed, and in that process, are often reduced in severity and
amount, and are sometimes vacated.
During the year ended December 31, 2021, neither the Company's current mining operations nor it's closed mines: (i) were
assessed any Mine Act section 104(b) orders for alleged failure to totally abate the subject matter of a Mine Act section 104(a)
citation within the period specified in the citation; (ii) were assessed any Mine Act section 110(b)(2) penalties for failure to
correct the subject matter of a Mine Act section 104(a) citation within the specified time period, which failure was deemed
flagrant (i.e., reckless or repeated failure to make reasonable efforts to eliminate a known violation that substantially and
proximately caused, or reasonably could have been expected to cause, death or serious bodily injury); (iii) received any Mine
Act section 107(a) imminent danger orders to immediately remove miners; or (iv) received any MSHA written notices under
Mine Act section 104(e) of a pattern of violation of mandatory health or safety standards or of the potential to have such a
pattern. In addition, there were no mining-related fatalities at the Company's operations or it's closed mines during the year
ended December 31, 2021.
The following table sets forth the total number of specific citations and orders, the total dollar value of the proposed civil
penalty assessments that were issued by MSHA, the total number of legal actions initiated and resolved before the Federal Mine
Safety and Health Review Commission ("FMSHRC") during the year ended December 31, 2021, and the total number of legal
actions pending before the FMSHRC at December 31, 2021, pursuant to the Mine Act, by individual mine at NACoal:
Mine Act
Section 104
Significant &
Substantial
Citations (2)(3)
Mine Act
Section
104(d)
Citations
Total Dollar
Value of
Proposed
MSHA
Assessment
Number of Legal
Actions Initiated
before the
FMSHRC for the
year ended at
December 31,
2021
Number of Legal
Actions Resolved
before the
FMSHRC for the
year ended at
December 31,
2021
Number of Legal
Actions Pending
before the
FMSHRC at
December 31,
2021
—
1
1
—
—
—
2
—
—
—
—
—
—
1
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
1
6
—
$
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
250
1,284
636
—
133
125
2,034
—
—
—
—
929
—
2,558
—
—
—
—
—
—
—
—
—
279
—
—
202
—
146
—
1,307
9,883
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
Name of Mine or Quarry (1)
Coteau (Freedom Mine)
Falkirk (Falkirk Mine)
Sabine (South Hallsville No. 1 Mine)
Demery (Five Forks Mine)
Caddo Creek (Marshall Mine)
Coyote Creek (Coyote Creek Mine)
Bisti Fuels (Navajo Mine) (4)
MLMC (Red Hills Mine)
North American Mining Operations:
Alico Quarry
Card Sound Quarry
Center Hill Quarry
FEC Quarry
Inglis Quarry
Krome Quarry
SCL Quarry
St. Catherine Quarry
Seven Diamonds Quarry
Central State Aggregates Quarry
Johnson County Quarry
Little River Quarry
Mid Coast Aggregates Quarry
Newberry Quarry
County Line Quarry
Palm Beach Aggregates Quarry
Perry Quarry
Queensfield Mine
Rosser Quarry
SDI Aggregates Quarry
West Florida Aggregates Quarry
Titan Corkscrew Quarry
White Rock Quarry - North
Total
(1) Bellaire's, Centennial's and Liberty's closed mines are not included in the table above and did not receive any of the indicated citations.
(2) Mine Act section 104(a) significant and substantial citations are for alleged violations of a mining safety standard or regulation where there exists a
reasonable likelihood that the hazard contributed to or will result in an injury or illness of a reasonably serious nature.
(3) The reported significant and substantial citation at Sabine during the year ended December 31, 2021, was originally classified by MSHA as significant
(4)
and substantial. The citation has been reduced to non-significant and substantial.
The contract mining agreement between Bisti Fuels and its customer was terminated effective September 30, 2021.
(THIS PAGE INTENTIONALLY LEFT BLANK)
Directors
J.C. Butler, Jr.
President and Chief Executive Officer,
NACCO Industries, Inc. and The North American
Coal Corporation
John S. Dalrymple
Former Governor of the State of North Dakota
John P. Jumper
Retired Chief of Staff, United States Air Force
Dennis W. LaBarre
Retired Partner, Jones Day
Michael S. Miller
Retired Managing Director, The Vanguard Group
Richard de J. Osborne
Retired Chairman and Chief Executive Officer,
ASARCO Incorporated
Alfred M. Rankin, Jr.
Non-Executive Chairman, NACCO Industries, Inc.
Chairman and Chief Executive Officer,
Hyster-Yale Materials Handling, Inc.
Non-Executive Chairman,
Hamilton Beach Brands Holding Company
Matthew M. Rankin
President and Chief Executive Officer,
Carlisle Residential Properties
Roger F. Rankin
Self-employed (personal investments)
Lori J. Robinson
Retired General, United States Air Force
Robert S. Shapard
Chairman and Retired Chief Executive
Officer of Oncor Electric Delivery Company
Britton T. Taplin
Self-employed (personal investments)
Leadership
J.C. Butler, Jr.
President and Chief Executive Officer
Carroll L. Dewing
Vice President – Operations
Philip N. Berry
President, North American Mining
Brian M. Larson
President, Catapult Mineral Partners
John D. Neumann
Vice President, General Counsel and Secretary
Eric S. Anderson
President, Mitigation Resources of North America
J. Patrick Sullivan, Jr.
Vice President and Chief Financial Officer,
The North American Coal Corporation
Eric A. Dale
Treasurer and Senior Director, Financial Planning
and Analysis, The North American Coal Corporation
Elizabeth I. Loveman
Vice President and Controller, NACCO Industries, Inc.
Sarah E. Fry
Associate General Counsel and Assistant Secretary
Thomas A. Maxwell
Vice President – Financial Planning and Analysis
and Treasurer, NACCO Industries, Inc.
Miles B. Haberer
Associate General Counsel, Assistant Secretary and
President, North American Coal Royalty Company
Andrew B. Hart
Controller, The North American Coal Corporation
Matthew J. Dilluvio
Associate Counsel and Assistant Secretary
NACCO Industries®
NACCO Industries®
Corporate Information
Form 10-K
Additional copies of the Company’s Form 10-K
filed with the Securities and Exchange Commission
are available free of charge through NACCO
Industries’ website (nacco.com) or by request to
Investor Relations
Investor Relations Contact
Investor questions may be addressed to:
Investor Relations
NACCO Industries
5875 Landerbrook Drive, Suite 220
Cleveland, Ohio 44124
or sent through the Company’s website.
Visit Our
Websites
Watch Our
Video
NACCO Industries: nacco.com
NACCO Natural Resources: nacco.com
North American Coal: nacoal.com
North American Mining: namining.com
Mitigation Resources of North America: mitigate.pro
Catapult Mineral Partners: catapultmp.com
Annual Meeting
The Annual Meeting of Stockholders of NACCO
Industries, Inc. will be held on May 18, 2022, at
11:00 a.m. located at:
5875 Landerbrook Drive
Cleveland, Ohio 44124
Stock Exchange Listing
The New York Stock Exchange Symbol: NC
Stock Transfer Agent and Registrar
Stockholder Correspondence:
Computershare
P.O. Box 505000
Louisville, KY 40233-5000
Overnight Correspondence:
Computershare
462 South 4th St., Suite 1600
Louisville, KY 40202
(800) 622-6757 (U.S., Canada and Puerto Rico)
(781) 575-4735 (International)
Legal Counsel
McDermott Will & Emery LLP
444 West Lake Street
Chicago, Illinois 60606
Independent Registered Public
Accounting Firm
Ernst & Young LLP
950 Main Ave., Suite 1800
Cleveland, Ohio 44113
Operations
14
NACCO Industries®
5875 Landerbrook Drive, Suite 220 • Cleveland, Ohio 44124
An Equal Opportunity Employer