®
Leading into
the Future
2 0 2 0 A n n u a l R e p o r t
Together We Lead
2
NACCO Industries®
Our Operations
NACCO Industries, Inc .®, through a portfolio of mining and natural
resources businesses, operates under three business segments: Coal
Mining, North American Mining and Minerals Management . The Coal Mining
segment operates surface coal mines under long-term contracts with power
generation companies and an activated carbon producer pursuant to a service-
based business model . The North American Mining segment provides value-added
contract mining and other services for producers of aggregates, lithium and other
minerals . The Minerals Management segment acquires and promotes the development
of oil, gas and coal mineral interests, generating income primarily from royalty-based lease
payments from third parties . In addition, the Company’s Mitigation Resources of North America®
business provides stream and wetland mitigation solutions .
About the Cover
We believe our people are the cornerstone of our success . Employees from
across the Company exhibit resiliency and perseverance in everything they
do, from safety programs and environmental stewardship to community
support and outreach . Along with pictures of our operations, we are
highlighting a few of our employees on the cover and throughout this Annual
Report to show our appreciation for all they do to serve our customers .
t Opposite Page
Our expertise with draglines is unsurpassed . Shown here is a dragline operated
by North American Mining, digging aggressively . Small pictures (inset) include a
dragline at the Freedom Mine in North Dakota and employees from Mitigation
Resources of North America, North American Coal and North American Mining .
Contents
About the Company . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1
Selected Financial and Operating Data . . . . . . . . . . . . . . . . . . . 2
Letter to Stockholders . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4
Corporate Responsibility . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9
Form 10-K . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11
Directors and Officers . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 126
Corporate Information . . . . . . . . . . . . . . . . . . Inside Back Cover
1
Selected Financial
and Operating Data
NACCO Industries, Inc. and Subsidiaries
2020(1)
2019
Year Ended December 31
2018
(In thousands, except per share data)
2017(1)
2016(1)
Operating Statement Data:
Revenues . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Operating profit (loss) . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
$ 128,432
$ 13,448
$ 140,990
38,820
$
$ 135,375
43,624
$
$ 104,778
$ 32,814
$ 111,081
(1,659)
$
Income from continuing operations . . . . . . . . . . . . . . . .
Discontinued operations, net-of-tax(2) . . . . . . . . . . . . . .
Net income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
$ 14,793
–
$ 14,793
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 . . . . . . . . . . . . . . . . . . . . . . . . .
$
$
$
$
2.11
–
2.11
2.10
–
2.10
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 . . . . . .
$ 0.7675
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
$
2,956
26,651
$ 29,607
5 .02
–
5 .02
5 .00
–
5 .00
$
$
$
$
4 .17
0 .27
4 .44
4 .14
0 .27
4 .41
$
$
$
$
0 .43
3 .91
4 .34
0 .43
3 .89
4 .32
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 .0650
90 .55
$
32 .50
$
6,779
6,818
6,854
(1) During 2020, 2017 and 2016, the Company recorded non-cash impairment charges of $8 .4 million, $1 .0 million and $17 .4 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
NACCO Industries®
2016(1)
2020(1)
2019
Year Ended December 31
2018
(In thousands, except employee data)
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) . . . . . . . . . . . . . . . . . . . . . . . . . .
$ 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
$ 69,308
$ 668,021
$ 94,295
$ 220,293
$
$
(2,486)
(45,984)
$
$
52,784
(20,262)
$
$
54,622
(18,387)
$ 41,305
(15,005)
$
$ 93,935
(9,817)
$
$
(48,470)
$
32,522
$
36,235
$ 26,300
$ 84,118
Provided by (used for) financing activities(4) . . . . . . . .
$ 14,028
$
5,113
$
(52,578)
$
(2,306)
$
(55,710)
Other Data:
Total employees at December 31(6) . . . . . . . . . . . . . . . . .
2,000
2,400
2,400
2,300
3,600
(4) Includes both continuing operations and discontinued operations for all years presented .
(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 housewares business in 2016 and the unconsolidated mines for all years presented .
2020(1)
2019
Year Ended December 31
2018
(In thousands)
2017(1)
2016(1)
Calculation of Adjusted EBITDA from
continuing operations(7)
Net income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Discontinued operations, net of tax . . . . . . . . . . . . . . . .
Long-lived asset impairment charges(1) . . . . . . . . . . . .
Income tax provision (benefit) . . . . . . . . . . . . . . . . . . . . .
Interest expense . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Interest income . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
Depreciation, depletion and amortization expense . .
Adjusted EBITDA from continuing operations(7) . . . . .
$ 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
$ 29,607
(26,651)
17,443
(9,649)
4,318
(196)
13,050
$ 27,922
(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 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
To Our Stockholders
Managing change seemed to be the constant in 2020 . We
modified how we work and live in response to the global COVID-19
pandemic and dealt with disappointing news from certain of our
customers, while continuing to execute our plans for growth and
diversification . In a year of change, transition and challenges, our
team adapted and charged ahead, leading us into the future .
Our employees showed dedication and resiliency as they
supported our customers in the wake of the global pandemic .
I’m incredibly proud of our team . Our culture, the common fiber
of our company, is built on safety, integrity and quality – we
believe in doing the right thing every time, and we do . Our safety
mindset allowed us to move quickly at the onset of the COVID-19
mines in 2022 and 2023, respectively, and to close the mines .
Falkirk’s customer has indicated a willingness to transfer
ownership of the power plant and mine, which could allow
operations to continue past 2022 . While we are working to
support those efforts, there is no guarantee that a solution will
be found . Also, in 2020, our contract to operate the Camino Real
Fuels Mine was terminated when our customer’s contract to sell
coal in Mexico was prematurely terminated, and the Caddo
Creek Mine entered reclamation after its customer was acquired
by a competitor .
We are highly engaged in activities to support our coal
customers through a key strategic initiative we call Protect the
Our culture, the common fiber of our company,
is built on safety, integrity and quality - we believe in
doing the right thing every time.
pandemic . We took deliberate and immediate actions, including
implementing the Centers for Disease Control and Prevention’s
recommended safety protocols across our operations, to
keep employees safe so we could continue operating as an
essential business during the pandemic . We also mobilized
a cross-functional task force focused on understanding and
communicating critical safety and operating issues related to the
pandemic . While some employees were able to transition to a
remote working environment, the vast majority of our employees
remained on-site to deliver the highest levels of customer service
and operational excellence . This is a real testament to the talent,
dedication and strength of our team .
Our Coal Mining business also faced challenges in 2020
beyond COVID-19 . Customers for our Falkirk and Sabine Mines
announced plans to retire the power plants supplied by those
Core . We work diligently to drive down coal production costs and
maximize efficiencies and operating capacity, while operating
safely, to help customers with management fee contracts improve
their competitiveness . These activities benefit our customers and
our company, as coal cost is a significant driver for power plant
dispatch . Increased power plant dispatch results in increased
demand for coal by our customers .
While the development of new mines to supply newly built
coal-fired power plants remains unlikely, growth could come
by assuming operations of existing mines, similar to the way
we became the operator of the Navajo Mine in New Mexico in
2017 . 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 new coal mining
projects we consider .
▼ Safety is always the top priority at every location . Ongoing safety training and communication ensures everyone is committed to keeping themselves and
their co-workers safe . Everyone at our mine sites and quarries must wear personal protection equipment .
4
We are fully aware of the political and economic pressures
related to CO₂ emissions that our customers face, and the
challenges that our legacy Coal Mining business faces . In
addition, company- and customer-controlled coal reserves are
being depleted with each year of mining, while the expiration
dates on our coal contracts draw closer . In this context, we
recognize that we must continue to adapt with a sense of
urgency befitting the ongoing disruption in the coal industry .
That is why we continue to execute on key initiatives developed
over the last several years as part of a core strategy to Grow
and Diversify . We are purposefully and deliberately diversifying
into other businesses that leverage our core skills, capabilities
and reputation . For more than 100 years, our company has
repeatedly demonstrated its ability to adapt to change, and today
is no different . We are building a strong portfolio of affiliated
businesses for growth and diversification, with long-term income
growth targets that exceed our projected levels of future coal-
related income .
We are well-positioned for growth in our North American
Mining business . This business started with our operation of one
dragline at a single limestone quarry for one customer in south
Florida in 1995 . We celebrated 25 years of continued deliveries
to that customer in 2020 . Our efforts to grow this business have
been successful and give us confidence for the future . In 2015, just
five years ago, we worked with two customers at seven quarries
operating 10 draglines, all in the southern part of Florida . Through
a deliberate focus on growth and diversification, we ended 2020
serving 10 customers at 20 quarries operating 32 draglines and a
rope-shovel, and we are developing a greenfield lithium project in
Nevada . The pandemic slowed North American Mining’s business
development initiatives in 2020, but our outlook for growth in
2021, including growth outside Florida, is strong .
North American Mining President Phil Berry has overseen
this period of rapid growth at North American Mining and leads
our ongoing activities to grow and diversify this business . Phil
holds B .S . and M .S . degrees in mining-related fields and has a
long career in the mining industry, including at our Sabine Mine in
Texas . This business is supported by a strong team of operational
experts who work each day to serve our customers .
in a broad range of geographies, and with more large-scale
projects than in prior periods . Importantly, we are seeing
increased opportunities to provide mining services for a broad
range of minerals that extend beyond limerock .
North American Mining is working with Lithium Americas (TSX
and NYSE: LAC) to develop the largest-known lithium resource in
the United States, the Thacker Pass Project in northern Nevada .
North American Mining will provide comprehensive mining
services with responsibility for all operational aspects of the
lithium mine, similar to our typical scope of work at a coal mine .
We will perform these services for Lithium Americas under a long-
term, hybrid management-fee mining contract . In January 2021,
the Thacker Pass Project received a Record of Decision from the
U .S . Bureau of Land Management . Additional permitting decisions
are expected later in 2021, and production is expected to begin in
the second half of 2022 .
Our diversification from coal into mining limestone,
aggregates and lithium demonstrates our ability to develop a
diversified mining-services business and provide value-added
mining services for a wide range of customers . Investments
in people, systems and infrastructure in recent years have
served us well throughout the pandemic and are expected to
allow us to grow this part of our business without substantial
additions to overhead . Our goal is to build North American
Mining into a leading provider of contract mining
services for customers who produce a wide
variety of minerals and materials . We believe
North American Mining 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 .
We continue to pursue growth opportunities in dragline
operations, as well as more comprehensive mining services
where we would operate a broader range of specialized
mining equipment for customers across the country .
Our capabilities build on decades of experience
operating draglines and a diverse fleet
of surface mining equipment . Today,
North American Mining’s pipeline of
potential projects is larger than
ever, with opportunities
spanning a diverse
group of customers
Mitigation
Resources of
North America offers
opportunity for growth and
diversification in an area where we
have substantial expertise and a very strong
reputation. Mitigation Resources acquires properties
with impaired streams, wetlands or species habitats, and
restores, enhances and preserves them, creating mitigation credits
that can be sold to off set nearby disturbances by others. In addition,
Mitigation Resources provides services for permittee-responsible mitigation
projects, such as the Tobaksákola Mitigation Site, shown here.
5
NACCO Industries®
Whether mining coal in North Dakota or Mississippi or
limestone in Florida, our commitment to customer
satisfaction, operational excellence, safety and
environmental stewardship shows clearly in
everything we do.
Clockwise from top left , a dragline in
North Dakota moves overburden to
uncover a seam of coal; a dragline
operator with Mississippi Lignite
Mining Company is focused
on safe operations; and
an employee safely
overseeing activity at
a North American
Mining site.
6
Our Minerals Management business is built from our historical
ownership of mineral rights in the natural gas-rich Marcellus and
Utica basins in southeastern Ohio . These mineral rights were
acquired decades ago, when we were actively mining coal in that
part of the country . Technological advancements for domestic
production of oil and gas, and new and upgraded transportation
pipelines serving this area, allowed rapid development and
monetization of these mineral reserves over the last few years .
We began executing on our strategy to Grow and Diversify
the Minerals Management business in 2020 with the acquisition
of $14 .2 million of mineral and royalty interests in the Permian
Basin in Texas . These acquisitions represent the first step in a
disciplined acquisition plan to expand our geographic footprint
Mitigation Resources of North America made excellent
progress in 2020 as it expanded operations into multiple states
across the southeastern part of the country . Mitigation Resources
provides stream and wetland mitigation solutions by developing
mitigation banks on its own or in conjunction with land owners
and others . This business offers opportunity for growth and
diversification in an industry where we have substantial expertise
and a very strong reputation, built on decades of high-quality
environmental work at our mining operations . Mitigation
Resources acquires properties with impaired streams, wetlands,
or species habitats and restores, enhances and preserves them,
creating mitigation credits that can be sold to offset nearby
disturbances by others . Mitigation Resources also provides
Our goal is to build North American Mining into
a leading provider of contract mining services for customers
who produce a wide variety of minerals and materials.
of mineral and royalty interests and diversify into a more
balanced mix of oil and gas assets across a range of development
stages that include undeveloped interests . Our initial focus is
generally in oil-rich basins offering diversification from our legacy
mineral interests .
We established Catapult Mineral Partners to manage this
part of our business, and have built a small but highly effective
staff with low overhead and advanced technology, to advance our
strategies . Catapult President Brian Larson, a West Point graduate
and petroleum engineer with an MBA, oversees our Minerals
Management business, managing our legacy assets and leading
our acquisition program .
Our minerals acquisition strategy focuses on developing
external relationships and leveraging in-house expertise to identify
and acquire interests in high-quality oil and gas resources at
advantageous prices . While we will fund the initial investment to
acquire these interests, we will not incur any development capital
expenditures thereafter, as all further development costs are
entirely borne by third-party producers who lease the minerals .
Our return on investment in this business comes from receiving
a royalty interest derived from production revenue generated by
the third-party producers . This business model for the Minerals
Management business can deliver higher average operating
margins over the life of a reserve, compared with traditional oil
and gas companies that bear the cost of exploration, production
and/or development . Our goal is to construct a diversified
portfolio of high-quality oil and, to a lesser extent, gas, mineral
and royalty interests in the United States that deliver near-term
cash flow yields and long-term projected growth . We believe
this business will provide unlevered after-tax returns on invested
capital in the low-to-mid-teens as our portfolio of reserves and
mineral interests grows and this business model matures .
mitigation advisory services using our service-based business
model to design and implement mitigation projects on behalf
of others .
Mitigation Resources is led by Eric Anderson, who has more
than 20 years of management and technical experience in “Waters
of the United States” identification, functional assessment,
permitting and restoration services . Eric holds a Ph .D . in soil
science from North Carolina State University and spent time as
a research scientist focused on carbon sequestration in wetland
ecosystems, along with previously serving as Environmental
Manager at our Sabine Mine in Texas .
Our 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, we
believe that Mitigation Resources can provide solid rates of return
as this business matures .
It is clear that we are a company in transition . While we
continue to believe that coal represents a reliable source of power,
our coal-related Protect the Core efforts are balanced by our
work to Grow and Diversify into new lines of business, each with
promising prospects . As the nature of our business evolves, we are
midway through an initiative that will better describe what each
of our businesses does and how each business delivers value .
Support for our portfolio of businesses is provided by a
lean corporate group . Our efforts to effectively and strategically
manage costs led us to initiate a voluntary separation program
in the fourth quarter of 2020 . This program, and natural
attrition, reduced headcount at our headquarters locations by
approximately 25% . As a company with a historically strong
employee-retention rate and deep roots in our communities, it
was difficult to see employees leave . However, we believe we
7
NACCO Industries® will be able to gain efficiencies as we continue to rethink how we
operate in a more streamlined manner, including through the use
of technology and innovation .
Our 2020 financial results were disappointing . As we entered
2020, we expected a decrease in operating profit in the Minerals
Management segment compared with 2019 due to low natural
gas prices and the natural decline in production expected at
newer natural gas wells in Ohio . The pandemic made natural
gas market conditions worse than expected, which negatively
affected our results, and we also experienced a reduction in
earnings in the Coal Mining segment as we dealt with transition
Robinson served in the United States Air Force and at retirement
was serving as Commander, North American Aerospace Defense
Command (NORAD) and United States Northern Command
(USNORTHCOM), where she became the United States’ first
female combatant commander . We are privileged to have General
Robinson as a director .
During 2020, Tim Light retired from our Board of Directors .
Mr . Light added tremendous value as a thoughtful and committed
Board member during his tenure and I would like to thank him for
his service . I would also like to welcome Bob Shapard, who joined
our Board of Directors in September 2020 . Mr . Shapard is the
We believe our two key strategies – Protect the Core and Grow and
Diversify– provide the right balance as we chart our future.
in the coal industry . For the year ended December 31, 2020, we
reported net income of $14 .8 million compared with net income of
$39 .6 million in 2019 . Despite the challenges experienced in 2020,
we continue to have a positive view of our long-term business
prospects, given our strategy to Grow and Diversify, a strong
pipeline of business development opportunities and the quality of
our team .
NACCO is fortunate to have long-term stockholders,
talented and dedicated people and a strong capital structure .
Our disciplined approach to capital allocation allowed us to end
2020 with a cash balance of $88 .5 million, debt of $46 .5 million,
and equity of over $300 million, giving NACCO ample financial
flexibility to continue to execute our strategy to Grow and Diversify .
While we may consider growth through acquisition, we would
be very selective in any M&A activity, and we will not take on
excessive debt . Our priorities for capital remain unchanged:
fund needed capital expenditures for existing businesses while
investing in initiatives that will drive future growth . While we
maintain a disciplined approach to investing capital, we also
continue to return cash to stockholders through dividends and,
as appropriate, share repurchases .
I would like to recognize General (Ret .) Lori Robinson,
who joined our Board of Directors in September 2019 . General
chairman of the Board of Oncor Electric Delivery Co . LLC, where
he served as CEO from April 2007 until March 2018 . He is also a
director at Oncor Electric Delivery Holdings Co . LLC and Leidos
Holdings, Inc . Mr . Shapard is adding great value to our Board and
we are excited to be working with him .
Our employees, management team and Board are strongly
aligned in our commitment to create long-term stockholder
value, with an eye on taxable investors . We are committed to
maintaining a strong balance sheet, and ultimately, we believe
our two key strategies – Protect the Core and Grow and Diversify –
provide the right balance as we chart our future .
While 2020 was not an easy year, I am awed by the tremen-
dous accomplishments of our incredible team of employees,
and I am proud of the progress we made to advance our goals .
Together, as a team, we look forward to building on our
108-year history . ▲
J.C. Butler, Jr.
President and Chief Executive Officer,
NACCO Industries, Inc. and
The North American Coal Corporation
8
Corporate Responsibility
Corporate responsibility has been a cornerstone of our
company for decades, long before environmental, social and
governance (ESG) nomenclature was developed . We hold
ourselves to high standards . Quite simply, we believe we have a
responsibility to do the right thing, every time, in every situation .
This core value of responsible behavior shapes our approach
to all relationships, our focus on safety, our involvement in
the communities where we live and work, and our care for the
environment . Our reputation is important to us . We recognize
that our legacy will determine our future, so we operate with a
long-term perspective . We operate this way because it is in the
long-term best interest of our employees, our company and our
stockholders .
Long-term thinking is part of our culture, our corporate DNA .
Our company was founded in 1913, and we continue to operate
in the communities where our business began . Descendants of
Frank Taplin, our founder, continue to own a substantial portion
of our stock today and are deeply committed to the company
and its future . Five generations of stock ownership provide a
long-term perspective that few companies enjoy . A number of our
institutional investors have owned our stock for many years as well .
We firmly believe that good corporate governance and long-
term success are inextricably linked . 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 has long maintained strong
governance practices, designed to ensure accountability, fiscal
responsibility and the highest levels of ethical conduct . 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 .
While NACCO may be viewed as having certain characteristics
bring valuable additional attributes, skills and experience . The
strength of our corporate governance structure is sustained by
a careful balancing and delineation of the roles of our Board,
management and stockholders . We believe that our governance
structure offers us a distinct competitive advantage by allowing
long-term thinking and decision-making to guide our way,
including our approach to social and environmental matters .
In 2020, we established an employee-led ESG Advisory
Group which is responsible for providing thoughtful input
on our corporate social and environmental responsibility
initiatives . Areas of focus include people, safety, community and
environmental responsibility . We have a strong record in each of
these focus areas, and we see opportunities to better highlight
our work and progress .
Our people are our greatest asset . To attract and retain the
best people, we provide competitive compensation and benefits,
as well as extensive training and educational assistance programs
to all employees . We believe in open communication at all levels
of the company, insist that everyone be treated with dignity and
respect and operate as a team . We provide opportunities for
employees to expand their skill sets, and in doing so provide
employees with opportunities to grow and develop within
our organization . As a result, we enjoy a high level of
employee engagement and an extraordinarily high
employee-retention rate . We are fiercely proud
of what we do, and our employees share a
strong bond . Looking out for one another
is a key part of the pact between
each of us .
For over 25 years, we
have utilized a restricted
stock employee
compensation
plan which
of a closely held corporation, our Board has annually decided
to comply with the independence rules of the New York Stock
Exchange . Independent directors make up a majority of our
Board (nine of 12), and independent directors chair each
of the key Board committees . In fact, no members of
the extended founding family serve on any of the
Audit Review, Compensation or Nominating
and Corporate Governance Committees .
Our Board includes a balance of
longer-tenured members with
in-depth knowledge of our
business and newer
members who
We believe coal represents a
We are
reliable source of power, our efforts
committed
to support our coal customers are balanced
to a strong legacy of
with our work to grow and diversify into new lines
environmental stewardship. In
of business, each with promising prospects for the future.
every instance, we aim to leave the land
As a result of our focus on diversification and growth, new
better than we found it. Our natural resource
businesses such as Catapult Mineral Partners and Mitigation Resources
reclamation process includes planting and maintaining
of North American allow us to provide additional value.
thousands of trees, acres of native grasses and other flora.
Many of us live in the very same communities where we work, and we
value and act as good stewards of these local natural resources.
9
NACCO Industries®
now covers more than 30 of our senior leaders . Performance is
measured against prescribed factors that include specific financial
metrics and progress toward meeting strategic goals . Employees
take full ownership of their shares on the date granted, and
are required to maintain ownership for a number of years after
issuance – three, five or 10 years, depending on role . We believe
this equity-based incentive plan motivates our leaders to maintain
a long-term perspective on decision making – aligning them with
our Board’s vision and our stockholders’ long-term best interest .
Safety is our number-one priority . Each day, we commit to
every employee that we will provide a safe working environment,
and in return we ask every employee to commit to working safely,
so that every employee goes home safe at the end of the work
day . The National Mining Association ranks us as an industry
be more than 80 miles away . We are proud to provide local support
for this important asset to the community . We also provide a
company-wide matching gift program through which we match
charitable donations, dollar for dollar, up to $5,000 per employee,
helping our employees raise funds for organizations they believe in .
We are committed to a strong legacy of environmental
stewardship . In every instance, we aim to leave the land better
than we found it . Our natural resource reclamation process
includes planting and maintaining thousands of trees, acres of
native grasses and other flora . Many of us live in the very same
communities where we work, and we value and act as good
stewards of these local natural resources . Our commitment to
productive reclamation is demonstrated by the fact that we have
received more than 90 federal and state awards for successful and
Safety is our #1 priority. Each day, we commit to every
employee that we will provide a safe working environment, and
in return we ask every employee to commit to working safely.
leader in safety, and we are proud that we have earned more
than 100 safety awards at the state and national levels . Our lost-
time accident rate is consistently below the national average for
comparable mines, and we continue to emphasize the importance
of safety at all of our operations . During 2020, five of our mine
sites completed the year with no lost-time accidents . Several of
our mines have operated for many years without such accidents .
For example, Demery Resources celebrated eight years without a
lost-time accident and Bisti Fuels celebrated three years without a
lost-time accident in 2020 . We continue to strive for zero lost-time
accidents and zero reportable incidents each and every day .
We are actively engaged in the local communities where
our employees live and work by supporting employees in their
volunteer activities, providing financial support to local non-
profits, and providing stable, well-paying jobs . We invest in these
local communities to keep them strong . We are long-standing
supporters of literacy programs, provide support to local
educational and arts organizations, and dependably donate to a
wide range of local groups, from volunteer fire departments and
ambulance squads to 4-H Clubs and local school groups . Our
employees value these organizations and events, and we believe
providing this support is important .
As an example, we proudly support many community
initiatives in the western part of North Dakota, where close to half
of our employees live and work . We are long-term contributors
to the Sakakawea Medical Center in Hazen, North Dakota, which
provides important medical care in the area, including care for
many of our employees and their families . If the Sakakawea
Medical Center were to close, the nearest emergency room would
innovative reclamation projects over the last 30 years . We are very
proud that our Bisti Fuels mine received the Excellence in Surface
Coal Mining Reclamation Award from the U .S . Department of the
Interior’s Office of Surface Mining Reclamation and Enforcement
and the National Mineral Education Award from the Interstate
Mining Compact Commission in 2020 . These awards are presented
to coal mining companies that achieve the most exemplary
mining and reclamation work in the country . The North Dakota
Public Service Commission awarded the Excellence in Surface
Coal Mining and Reclamation Award to The Coteau Properties
Company for protecting and preserving a cultural site important
to local Native American history . The National Association of State
Land Reclamationists awarded its 2020 Mined Land Reclamation
Award to Demery Resources in recognition of the exemplary
concurrent reclamation work at the Five Forks Mine .
In fact, our strong legacy of environmental work led us to
create our new business, Mitigation Resources of North America®,
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 of the environment,
while allowing us to deliver tangible environmental benefits in
locations outside our normal mining operations .
We believe that our focus on developing and maintaining
strong relationships with people and communities, keeping
everyone safe and operating in an environmentally sensitive
manner are critical parts of our commitment to being a good
corporate citizen . We believe that the approach to governance
prescribed by our Board of Directors promotes our long-term
success . ▲
10
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, 2020
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, 2020 (the last business day of the
registrant's most recently completed second fiscal quarter): $96,645,091
Number of shares of Class A Common Stock outstanding at February 19, 2021: 5,490,948
Number of shares of Class B Common Stock outstanding at February 19, 2021: 1,566,877
DOCUMENTS INCORPORATED BY REFERENCE
Portions of the Company's Proxy Statement for its 2021 annual meeting of stockholders are incorporated herein by reference in Part III of this Form 10-K.
NACCO INDUSTRIES, INC.
TABLE OF CONTENTS
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
27
37
37
37
37
Item 5. MARKET FOR REGISTRANT’S COMMON EQUITY, RELATED STOCKHOLDER MATTERS AND ISSUER
38
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 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 I.
PART II.
PART III.
PART IV.
Item 15. EXHIBITS AND FINANCIAL STATEMENT SCHEDULES
SIGNATURES
FINANCIAL STATEMENTS AND SUPPLEMENTARY DATA
38
39
55
55
55
55
55
56
56
56
56
56
57
62
F-1
Item 1. BUSINESS
PART I
General
NACCO Industries, Inc.® (“NACCO” or the “Company”), through a portfolio of mining and natural resources businesses,
operates under three business segments: Coal Mining, North American Mining ("NAMining") and Minerals Management. The
Coal Mining segment operates surface coal mines under long-term contracts with power generation companies and an activated
carbon producer pursuant to a service-based business model. The NAMining segment provides value-added contract mining
and other services for producers of aggregates, lithium and other minerals. The Minerals Management segment acquires and
promotes the development of oil, gas and coal mineral interests, generating income primarily from royalty-based lease
payments from third parties. In addition, the Company has a business providing stream and wetland mitigation solutions.
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 of North America® (“MRNA”) and Bellaire Corporation
(“Bellaire”). MRNA generates and sells stream 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.
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.
The Company has continued to operate as an essential business during the COVID-19 pandemic because it supports critical
infrastructure industries. The extent to which COVID-19 impacts the Company going forward will depend on numerous factors
and future developments that remain uncertain.
Business Strategy
The Company is leveraging its core mining and natural resources management skills to develop a strong and diverse portfolio
of affiliated businesses operating in the mining and natural resources industries while maintaining a conservative capital
structure. Diversified strategic growth is the key to enhancing net income as well as increasing free cash flow available to
continue to reinvest in and expand the businesses.
NAMining continues to expand the scope of its business development activities to grow and diversify by targeting
geographically diverse customers who require a broad range of minerals and materials. NAMining also continues to leverage
the Company’s core mining skills to expand the range of contract mining services provided, in addition to providing
comprehensive mining services to operate entire mines when appropriate, such as the long-term mining contract with Lithium
Americas to provide mining services for its Thacker Pass lithium project in Nevada.
The Company’s efforts to grow and diversify the Minerals Management segment include acquiring additional mineral interests
or similar investments in the energy industry. Once mineral and royalty interests have been acquired, the Minerals Management
segment will benefit from the continued development of its mineral properties without the need for investment of additional
capital. 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.
MRNA creates and sells stream and wetland mitigation credits and provides services to those engaged in permittee-responsible
mitigation. This business offers opportunity for growth and diversification in an industry where the Company has substantial
knowledge and expertise. MRNA has achieved impressive initial growth and is positioned for additional growth.
One of the Company’s core strategies is to pursue activities which can provide resiliency to its existing coal mining
operations. The Company works to drive down coal production costs and maximize 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.
The Company evaluates opportunities to expand its coal mining business, but opportunities are few. Low natural gas prices and
growth in renewable energy sources, such as wind and solar, are likely to continue to unfavorably affect the amount of
electricity dispatched from coal-fired power plants. 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. However, the
Company would consider opportunities where it can apply its management fee business model to assume operation of existing
1
surface coal mining operations in the United States. Outright acquisitions of existing coal mines or mining companies with
exposure to fluctuating coal commodity markets, or structures that would create significant leverage, are outside the Company’s
area of focus.
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.
Business Developments
During 2020, the Minerals Management segment acquired mineral interests for approximately 65.5 thousand gross acres and
1.2 thousand net royalty acres in the Permian Basin in Texas for a total purchase price of approximately $14.2 million. The
acquired interests align with the Company’s strategy of selectively acquiring mineral interests with a balance of near-term cash
flow yields and long-term growth potential, in oil-rich basins offering diversification from the Company’s legacy mineral
interests in predominately natural gas-rich basins.
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. On November 5, 2020, AEP announced it intends to retire the Pirkey Plant in 2023 in order
to comply with the U.S. Environmental Protection Agency’s Coal Combustion Residuals rule. The Sabine Mine delivered 1.9
million and 2.6 million tons to the Pirkey Plant in 2020 and 2019, respectively. During 2020, SWEPCO reduced its expected
future annual delivery requirements to be between 1.4 million and 1.7 million tons. The Sabine Mine contributed $3.9 million
and $4.6 million to NACCO’s Earnings from Unconsolidated Operations during 2020 and 2019, respectively.
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 that manufactures synthetic natural gas and produces fertilizers, solvents, phenol, carbon dioxide, and other
chemical products for sale. On November 5, 2020, Basin Electric informed its employees and 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 beginning in 2026. 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. As a result, coal deliveries to the Synfuels
Plant are expected to continue until at least 2026.
On September 30, 2020, Caddo Creek Resources Company, LLC's (“Caddo Creek's”) customer, a division of Cabot
Corporation, entered into a long-term supply agreement with a subsidiary of Advanced Emissions Solutions (“AES”) as well as
an agreement for the sale of the Marshall Mine, operated by Caddo Creek, to a subsidiary of AES. AES announced its intent to
close the Marshall Mine. Caddo Creek entered into a contract with a subsidiary of AES to perform the required mine
reclamation. The Marshall Mine delivered 0.1 million and 0.2 million tons during 2020 and 2019, respectively.
The contract mining agreement between Camino Real Fuels, LLC (“Camino Real”) and its customer, Dos Republicas Coal
Partnership (“DRCP”), terminated effective July 1, 2020 as a result of the unexpected termination by Comisión Federal de
Electricidad (“CFE”) of its coal supply contract with an affiliate of DRCP. The termination of the contract between CFE and
DRCP eliminated DRCP’s need for coal from Camino Real's Eagle Pass Mine, and resulted in mine closure. Mine reclamation
is the responsibility of DRCP. Camino Real has no legal obligation to perform mine reclamation. The Eagle Pass Mine
delivered 0.3 million and 1.6 million tons during 2020 and 2019, respectively.
On May 7, 2020, Great River Energy ("GRE"), Falkirk Mine's customer, announced its intent to retire the Coal Creek Station
power plant in the second half of 2022 and modify the Spiritwood Station power plant to be fueled by natural gas. As noted in
the announcement, GRE is willing to consider opportunities to sell Coal Creek Station. Falkirk Mine is the sole supplier of
lignite coal to Coal Creek Station pursuant to a long-term contract under which Falkirk also supplies approximately 0.3 million
tons of lignite coal per year to Spiritwood Station. Falkirk delivered a total of 7.2 million and 7.4 million tons of lignite coal and
contributed $16.1 million and $15.9 million to NACCO’s Earnings from Unconsolidated Operations during 2020 and 2019,
respectively.
In 2019, NAMining, through a new subsidiary, Sawtooth Mining, entered into a mining agreement to serve as exclusive
contract miner for the Thacker Pass lithium project in northern Nevada. The Thacker Pass Project is 100% owned by Lithium
Nevada Corp, a subsidiary of Lithium Americas Corp. Lithium Nevada plans to develop a lithium production facility near what
is believed to be the largest known lithium deposit in the United States. Sawtooth Mining will provide comprehensive mining
services similar to the Company's typical scope of work in the Coal Mining segment. The mining agreement provides that
2
Lithium Nevada will reimburse Sawtooth Mining for its operating and mine reclamation costs, and pay Sawtooth Mining a
management fee per metric ton of lithium delivered during the 20-year contract term commencing with receipt of construction
and operating permits by Lithium Nevada.
Coal Mining Segment
The Coal Mining segment, operating as 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 on the Navajo Nation in New Mexico. Each
mine is fully integrated with its customer's operations.
During 2020, the Company's operating coal mines were: Bisti Fuels Company, LLC (“Bisti”), Caddo Creek, Camino Real,
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. Bisti supplies sub-bituminous coal for
power generation. Demery supplies lignite coal for the production of activated carbon. Each of these mines deliver their coal
production to adjacent or nearby power plants, synfuels plants or an activated carbon processing facility under long-term supply
contracts. Each mine is the exclusive supplier of coal to its customers' facilities. MLMC’s coal supply contract contains a take
or pay provision; all other coal supply contracts are requirements contracts under which earnings can fluctuate. In addition,
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 providing all of the capital required to build and operate the mine. This contract structure
eliminates exposure to spot coal market price fluctuations while providing 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 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, the persistence of low diesel fuel prices can negatively affect 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.
The coal reserves at Coteau, Falkirk, Coyote, MLMC and Centennial Natural Resources ("Centennial") are owned or controlled
by the Company. The coal reserves at all other mines are owned or controlled by the respective mine’s customer. Total coal
reserves approximate 1.9 billion tons (including the unconsolidated coal mining subsidiaries), with approximately 0.7 billion
tons committed to customers pursuant to long-term contracts.
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
3
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.
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 operates primarily at limestone quarries
in Florida, but is focused on expanding outside of Florida and into mining materials other than limestone. In addition,
NAMining 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.
During 2020, the Minerals Management segment acquired mineral interests in the Permian Basin 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.
The acquisition criteria includes building a blended portfolio of mineral and royalty interests (i) with new wells anticipated to
come online within one to two years of investment, (ii) in areas with forecasted future development within five years after
acquisition, or (iii) with 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 and Williston basins 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 2020 acquisitions of mineral and royalty interests was $14.2 million, of which $12.0 million closed
in December 2020, $2.0 million closed in November 2020 and $0.2 million closed in August 2020. The acquisitions include
65.5 thousand gross acres and 1.2 thousand net royalty acres. The Company did not acquire any mineral interests in 2019.
Including the 2020 acquisitions, total mineral and royalty interests include approximately 109.2 thousand gross acres and 58.1
thousand net royalty acres.
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.
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. Holders of royalty interests are
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.
4
• 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.
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 information about Company’s best estimate of the number of gross and net
productive wells as of December 31, 2020:
Oil
Natural Gas
Total
Gross
Net
279
408
687
0.2
26.5
26.7
Gross wells are the total wells in which an interest is owned.
Net wells are the sum of the fractional interest owned in gross wells.
The majority of the Company’s producing mineral and royalty interest acreage is, 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.
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. 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
5
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.
In 2020, two customers individually accounted for more than 10% of consolidated revenue. In 2019, two customers and an oil
and gas lessee 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:
Percentage of Consolidated
Revenue
Segment
2020
2019
Coal Mining customer
NAMining customer
Minerals Management lessee
55 %
19 %
less than 10%
48 %
21 %
12 %
The loss of either of these customers or the lessee 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, 2020, the Coal Mining segment derived
approximately 60% of the Earnings of Unconsolidated Operations from two customers, Basin Electric and GRE. GRE
announced its intent to close Coal Creek station in 2022. 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 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. Sustained low natural gas prices have resulted in an increase in electricity generated from natural gas leading to a decline
in the use of coal-fired capacity in the United States. 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. As an example, the Company estimates wind capacity in North Dakota has increased
over 60% since 2015 to approximately 3,600 megawatts and wind developers have expressed an interest in building more than
3,000 megawatts of additional wind generation in North Dakota over the next several years. 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
begins 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 receives only a 10%
ITC.
Certain of the Coal Mining segment's customers continue to invest in efficiency and environmental upgrades to their facilities.
Because the Coal Mining segment's customers’ power plants are competitive suppliers of electricity in their respective dispatch
6
areas relative to other coal-fired generating units in those dispatch areas, the Company considers its surface coal mining
operations to be well positioned relative to most other mines servicing coal-fired generating units.
Based on industry information, the Company believes it was one of the five largest coal producers in the U.S. in 2020 based on
total coal tons produced.
NAMining faces competition from aggregates producers which choose to self-perform mining operations and from other
mining companies.
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 who 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 or human 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 and
human 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 limestone
demand.
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,
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, 2020, the Company and its subsidiaries had approximately 2,000 employees, including approximately
1,500 employees at the Company’s unconsolidated mining operations, of which 261 are represented by a union at Bisti.
NACCO believes it has good relations with both union and non-union employees.
NACCO believes its employees are critical to its success and invests in its employees by offering a competitive total rewards
package that includes a combination of salaries and wages, health and wellness benefits, retirement benefits and educational
benefits. The Company provides employee wages that are competitive and consistent with employee positions, skill levels,
experience, knowledge and geographic location. The Company recognizes the sustainability of its culture and success is
strengthened when employees are respected, motivated and engaged. The Company works to match employees with
assignments to 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. Employee safety in the workplace is
one of the Company’s core values. Hazards in the workplace are actively identified and management tracks incidents so
remedial actions can be taken to improve workplace safety. 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.
7
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 inactive textual references 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.
SEC Industry Guide 7 Information
The following map shows the Coal Mining segment's locations:
8
The location, mine type, reserve data, coal quality characteristics, sales tonnage and contract expiration date for the Coal
Mining segment were as follows:
COAL MINING OPERATIONS ON AN “AS RECEIVED” BASIS
2020
2019
Mine/Reserve
Unconsolidated Mines
Freedom Mine (c)-
The Coteau Properties Company
Falkirk Mine (c)(e)-
The Falkirk Mining Company
South Hallsville No. 1 Mine
(c)(f)(g)-
The Sabine Mining Company
Five Forks Mine (c)(f)-
Demery Resources Company, LLC
Marshall Mine (c)(f)(h)-
Caddo Creek Resources Company,
LLC
Type of
Mine
Surface
Lignite
Surface
Lignite
Surface
Lignite
Surface
Lignite
Surface
Lignite
Eagle Pass Mine (c)(f)(i)-
Camino Real Fuels, LLC
Surface
Bituminous
Surface
Lignite
Surface
Sub-
bituminous
Surface
Lignite
Surface
Bituminous
Coyote Creek Mine (c)-
Coyote Creek Mining Company,
LLC
Navajo Mine (c)(j)- Bisti Fuels
Company
Consolidated Mines
Red Hills Mine-
Mississippi Lignite Mining
Company
Centennial Natural Resources
Total Developed
Undeveloped Mines
North Dakota
Texas
Eastern (l)
Mississippi
Total Undeveloped
3.4
4.9
(h)
(i)
72.4
(j)
161.0
17.0
708.7
—
—
—
—
—
Proven and Probable Reserves (a)(b)
Committed
Under
Contract
Uncommitted
Total
(Millions of Tons)
Tons
Delivered
(Millions)
Owned
Reserves
(%)
Leased
Reserves
(%)
Total
Committed
and
Uncommitted
(Millions of
Tons)
Tons
Delivered
(Millions)
Contract
Expires
438.0
—
438.0
12.6
12.0
358.6
370.6
3 %
1 %
97 %
432.8
13.5
2022 (d)
99 %
375.7
7.4
2045 (e)
(f)(g)
(f)(g)
102.6
2.6
2035 (g)
(f)
(f)
4.9
0.1
2030
(f)(h)
(f)(h)
(f)(i)
(f)(i)
19.2
15.6
0.2
(h)
1.5
(i)
0 %
100 %
69.6
1.7
2040
(j)
(j)
(j)
5.0
2031
7.2
1.9
0.2
0.1
0.3
2.0
4.2
97.3
100.7
—
4.9
(h)
(i)
(h)
(i)
—
72.4
(j)
(j)
76.3
237.3
2.5
44 %
56 %
240.0
2.6
2032
—
17.0
532.2
1,240.9
—
31.0
40 %
60 %
221.4
221.4
210.3
210.3
41.0
41.0
188.2
188.2
660.9
660.9
—
—
—
—
—
100 %
100 %
100 %
100 %
43.0
1,303.4
243.9
222.5
41.0
188.2
695.6
1,999.0
—
(k)
34.6
—
—
—
—
—
Total Developed/Undeveloped
708.7
1,193.1
1,901.8
9
Type of Mine
Coal Formation or
Coal Seam(s)
Average
Seam
Thickness
(feet)
Average
Depth (feet)
BTUs/lb
Sulfur
(%)
Ash
(%)
Moisture
(%)
Average Coal Quality (As received)
Surface Lignite
Beulah-Zap Seam
16
100
6,700
0.90 %
9 %
36 %
Mine/Reserve
Unconsolidated Mines
Freedom Mine (c)-
The Coteau Properties Company
Falkirk Mine (c)-
The Falkirk Mining Company
South Hallsville No. 1 Mine (c)(f)-
The Sabine Mining Company
Five Forks Mine (c)(f)-
Demery Resources Company, LLC
Marshall Mine (c)(f)(h)-
Caddo Creek Resources Company,
LLC
Eagle Pass Mine (c)(f)(i)-
Camino Real Fuels, LLC
Surface Lignite
Hagel A&B, Tavis
Creek, Kinneman
Creek Seams
Surface Lignite
Wilcox Formation
Surface Lignite
Wilcox Formation I
Seam
Surface Lignite
Surface
Bituminous
(h)
(i)
Coyote Creek Mine (c)-
Coyote Creek Mining Company, LLC
Surface Lignite
Beulah-Zap Seam
Navajo Mine (c)(j)- Bisti Fuels
Company
Surface
Sub-bituminous
(j)
Consolidated Mines
Red Hills Mine-
Mississippi Lignite Mining Company
Surface Lignite
Centennial Natural Resources
Undeveloped Mines
Surface
Bituminous
C, D, E, F, G, H
Seams
Black Creek, New
Castle, Mary Lee,
Jefferson, American,
Nickel Plate, Pratt
Seams
8
3
115
6,200
0.62 %
11 %
38 %
85
6,448
0.79 % 18.2 %
32 %
4.4
44
7,033
0.44 %
7.8 %
37 %
(h)
(i)
10
(j)
(h)
(i)
(h)
(i)
(h)
(i)
(h)
(i)
(h)
(i)
95
6,900
0.93 %
9 %
35 %
(j)
(j)
(j)
(j)
(j)
3.4
150
5,100
0.60 %
15 %
43 %
1.75
178
13,226
2.00 %
10 %
4 %
North Dakota
Texas
Eastern
Mississippi
— Fort Union Formation
— Wilcox Formation
Freeport & Kittanning
Seams
—
— Wilcox Formation
13
5
4
5
130
6,500
120
6,800
400
12,070
130
5,200
0.8 %
1.0 %
3.3 %
0.6 %
8 %
16 %
12 %
13 %
38 %
30 %
3 %
44 %
(a)
(b)
(c)
(d)
(e)
Committed and uncommitted tons represent in-place estimates. The projected extraction loss is approximately 10% of the proven and probable
reserves, except with respect to the Eastern Undeveloped Mines, in which case the projected extraction loss is approximately 50% of the proven and
probable reserves.
The Company's reserve estimates are generally based on the entire drill hole database for each reserve, which was used to develop a geologic
computer model using triangulation methods and inverse distance to the second power as an interpolator for NACCO's reserves. As such, all
reserves are considered proven (measured) within the Company's reserve estimate. None of the Company's coal reserves have been reviewed by
independent experts. The Company’s estimate of the economic viability of the proven and probable reserve estimates for tons committed to
customers pursuant to long-term contracts are supported by existing long-term contracts to mine coal on behalf of customers and life-of-mine plans
associated with those contracts. The contracts with each customer of the Unconsolidated Mines eliminate Company exposure to spot coal market
price fluctuations. At the Unconsolidated Mines, compensation from each customer to the Company includes reimbursement of all mine operating
costs plus a contractually-agreed fee based on the amount of coal delivered. Red Hills Mine - 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.
MLMC is the exclusive supplier of coal to its customer’s power plant under its contract that runs through 2032. The Company’s assessment of the
economic viability of the mineral reserves associated with MLMC takes into account estimated customer demand, including the minimum annual
take provision in the contract, as well as cost of production. The economic viability of the uncommitted reserves assumes coal would be mined in a
mine-mouth operation that minimizes or eliminates transportation costs and under contract terms, which are similar to those contained in the
Company’s existing long-term management fee contracts, or leased to other miners. The majority of the Company’s uncommitted reserves are
located in close proximity to power generation or other facilities, which could allow a mine-mouth operation. Lessees of this coal generally would
mine the coal if the coal sale price would exceed the lessee operating costs. As to coal mined and sold by lessees, the Company would receive a
royalty based on a percentage of the sale price. See footnote (h) for coal reserves currently leased to others.
The contracts for these mines require the customer to cover the cost of the ongoing replacement and upkeep of the plant and equipment of the mine.
Although the term of the existing coal sales agreement terminates in 2027, the term may be extended for two additional periods of five years, or until
2037, at the option of the Company.
On May 7, 2020, GRE, Falkirk Mine's customer, announced its intent to retire the Coal Creek Station power plant in the second half of 2022 and
modify the Spiritwood Station power plant to be fueled by natural gas.
10
(f)
(g)
(h)
(i)
(j)
(k)
(l)
These reserves are owned or controlled by customers. The Company conducts activities to extract these customer-owned and controlled reserves
pursuant to long-term service contracts.
On November 5, 2020, AEP, Sabine Mine's customer, announced its intent to retire the Pirkey Plant in 2023 in order to comply with the U.S.
Environmental Protection Agency’s Coal Combustion Residuals rule.
On September 30, 2020, a division of Cabot Corporation, Marshall Mine's customer, entered into an agreement for the sale of the Marshall Mine to a
subsidiary of AES. AES announced its intent to close the Marshall Mine. Caddo Creek entered into a contract with a subsidiary of AES to perform
the required mine reclamation.
The contract mining agreement between Camino Real and its customer, DRCP, terminated effective July 1, 2020 and resulted in the closure of
Camino Real's Eagle Pass Mine.
These reserves are owned or controlled by Bisti's customer and it controls proven and probable reserve data. Bisti’s customer declined to allow us to
include the proven and probable reserve data in this Form 10-K. The Company conducts activities to extract these customer-owned and controlled
reserves pursuant to a long-term service contract.
Centennial ceased active mining operations at the end of 2015.
The proven and probable reserves included in the table do not include coal that is leased to others. The Company had 69.0 million tons and 70.0
million tons in 2020 and 2019, respectively, of Eastern Undeveloped Mines with leased coal committed under contract.
Unconsolidated Mines
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.
On November 5, 2020, Basin Electric informed its employees and 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 beginning
in 2026. 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. As a result, coal deliveries to the Synfuels Plant are expected to continue
until at least 2026.
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 381 leases
granting the right to mine approximately 34,715 acres of coal interests and the right to utilize approximately 23,575 acres of
surface interests. In addition, Coteau owns in fee 33,525 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.
Falkirk Mine — The Falkirk Mining Company
The Falkirk 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.
On May 7, 2020, GRE announced its intent to retire the Coal Creek Station power plant in the second half of 2022 and modify
the Spiritwood Station power plant to be fueled by natural gas. The Falkirk Mine delivered 7.2 million and 7.4 million tons of
lignite coal, primarily for the Coal Creek Station, during 2020 and 2019, respectively. The terms of the contract between the
Company and GRE specify that GRE is responsible for all costs related to mine closure, including but not limited to, final mine
reclamation costs, post-retirement medical benefits and pension costs with respect to Falkirk employees.
11
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 311 leases granting the right to mine approximately 43,084 acres of coal interests and
the right to utilize approximately 24,061 acres of surface interests. In addition, Falkirk owns in fee 41,275 acres of surface
interests and 1,789 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.
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.
South Hallsville No. 1 Mine — The Sabine Mining Company
The South Hallsville No. 1 Mine started 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.
On November 5, 2020, AEP announced it intends to retire the Pirkey Plant in 2023 in order to comply with the U.S.
Environmental Protection Agency’s Coal Combustion Residuals rule. The South Hallsville No. 1 Mine delivered 1.9 million
and 2.6 million tons to the Pirkey Plant in 2020 and 2019, respectively. During the third quarter of 2020, SWEPCO reduced its
expected future annual delivery requirements to be between 1.4 million and 1.7 million tons. The terms of the contract between
the Company and SWEPCO specify that SWEPCO is responsible for all costs related to mine closure, including but not limited
to, final mine reclamation costs, post-retirement medical benefits and pension costs with respect to Sabine employees.
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, operated by Demery, began delivering coal in 2012 and is located approximately three miles north of
Creston, Louisiana on State Highway 153. 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.
Marshall Mine — Caddo Creek Resources Company, LLC
On September 30, 2020, Caddo Creek's customer, a division of Cabot Corporation, entered into a long-term supply agreement
with a subsidiary of AES as well as an agreement for the sale of the Marshall Mine to a subsidiary of AES. AES announced its
intent to close the Marshall Mine. Caddo Creek entered into a contract with a subsidiary of AES to perform the required mine
reclamation. The Marshall Mine delivered 0.1 million and 0.2 million tons during 2020 and 2019, respectively.
Eagle Pass Mine — Camino Real Fuels, LLC
The Eagle Pass Mine, operated by Camino Real, began delivering coal in 2015 to Camino Real's customer, Dos Republicas
Coal Partnership ("DRCP"). The contract mining agreement between Camino Real and DRCP terminated effective July 1, 2020
as a result of the unexpected termination by Comisión Federal de Electricidad (“CFE”) of its coal supply contract with an
affiliate of DRCP. The termination of the contract between CFE and DRCP eliminated DRCP’s need for coal from Camino
Real's Eagle Pass Mine, and resulted in mine closure. Mine reclamation is the responsibility of DRCP. Camino Real has no
legal obligation to perform mine reclamation. The Eagle Pass Mine delivered 0.3 million and 1.6 million tons during 2020 and
2019, respectively.
Coyote Creek Mine - Coyote Creek Mining Company, LLC
In 2016, the Coyote Creek Mine began delivering coal to the Coyote Station owned by Otter Tail Power Company, Northern
Municipal Power Agency, Montana-Dakota Utilities Company and Northwestern Corporation. The Coyote Creek Mine
generally produces approximately 1.5 million to 2.5 million tons of lignite coal annually when Coyote Station is operating at
anticipated levels.
12
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.
Navajo Mine - Bisti Fuels Company, LLC
Bisti has been the contract miner at Navajo Transitional Energy Company's ("NTEC's") Navajo Mine since 2017. Bisti
generally delivers approximately 5.0 million tons of sub-bituminus coal to the Four Corners Power Plant when the plant is
operating at anticipated levels.
The Navajo Mine is located approximately 25 miles southwest of Farmington, New Mexico, off Indian Service Road 3005, and
is on the Navajo Nation. Access to the Navajo Mine is by means of a paved road. Bisti has no title, claim, lease or option to
acquire any of the reserves at Navajo Mine. NTEC, a wholly-owned limited liability company of The Navajo Nation, controls
all of the reserves within the Navajo Mine.
Consolidated Mines
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
7,061 acres of surface interest and 4,162 acres of coal interests. MLMC holds leases granting the right to mine approximately
5,953 acres of coal interests and the right to utilize approximately 5,850 acres of surface interests. MLMC holds subleases
under which it has the right to mine approximately 1,541 acres of coal interests. 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.
Centennial Natural Resources
Centennial ceased active mining operations at the end of 2015. Centennial and its affiliate, North American Coal Royalty
Company, own in fee approximately 5,602 acres of coal interests and approximately 2,323 acres of surface interests in
Alabama. Centennial holds leases in Alabama granting the right to mine approximately 3,907 acres of coal interests and the
right to utilize approximately 4,698 acres of surface interests. The majority of the leases held by Centennial were originally
acquired between 2000 and 2012 with terms that can be extended by the continuation of mining activities.
13
North American Mining
NAMining primarily operates and maintains draglines to mine limestone and sand at the following mines in Florida and
Virginia pursuant to mining services agreements with the mine owners:
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
Newberry
Titan Pennsuco
Location
Miami
Miami
Ft. Myers
Miami
Miami
Florida City
Zephyrhills
Customer
WRQ
Cemex
Cemex
Cemex
Cemex
Cemex
McDonald Group
Sumter County
McDonald Group
Hernando County
McDonald Group
Sumter County
Sumter County
Crystal River
Cemex
Cemex
Cemex
Ft. Myers
Titan America
Loxahatchee
Palm Beach Aggregates
Lamont
Martin Marietta
Florida City
Blue Water Industries
King William
County, VA
Pasco County
Alachua County
Miami
King William Sand and
Gravel Company, Inc.
K&M Pasco 130
Holdings, LLC
Argos USA, LLC
Titan America
Year NACCO
Started Operations
1995
2003
2004
2005
2006
2009
2016
2016
2016
2016
2016
2016
2017
2017
2018
2018
2018
2019
2019
2020
NAMining's customers control all of the limestone and sand reserves within their respective mines.
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.
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.
14
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.
NAMining has no title, claim, lease or option to acquire any of the reserves at any of the mines where it provides services.
General Information
Leases. The leases held by Coteau, Coyote Creek, Falkirk and MLMC have a variety of continuation provisions, but generally
permit the leases to be continued beyond their fixed terms. Centennial holds the mining rights to certain of its reserves through
fee ownership, and leases and licenses from the coal and surface owners. NACCO expects coal will be available to meet
customers' future production requirements utilizing land and reserves that are currently owned or leased or accessible through
ownership acquisition or new leases.
Previous Operators. There were no previous operators of the Freedom Mine, Falkirk Mine, South Hallsville No. 1 Mine, Five
Forks Mine, Marshall Mine, Eagle Pass Mine, Coyote Creek Mine or Red Hills Mine. NTEC's Navajo Mine was previously
operated by a third party.
Exploration and Development. All coal mines are well past the exploration stage. Additional pit development is under way at
each operating mine. Drilling programs are routinely conducted for the purpose of refining guidance related to ongoing
operations. For example, at the Red Hills Mine, the lignite coal reserve has been defined by a drilling program that is designed
to provide 500-foot spaced drill holes for areas anticipated to be mined within four years of the current pit. Drilling beyond the
four-year horizon ranges from 1,000 to 2,000-foot centers. Drilling is conducted annually to stay current with the advance of
mining operations. Geological evaluation is in process at all operating locations.
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. The majority of electrical power for the draglines, shovels, coal crushers, coal conveyors and facilities
generally is provided by the power generation customer for the applicable mine. Electrical power for the Sabine facilities is
provided by Upshur Rural Electric Co-op. Electrical power for the Sabine dragline operating in the South Marshall permit area
is provided by Southwestern Electric Power Company. Electrical power for the draglines operating in Sabine's Rusk permit area
is provided by Rusk County Electric Co-op. Electrical power for the MLMC draglines and shovels is provided by 4-County
Electric Power Association. The remainder of the equipment generally is powered by diesel fuel or gasoline.
15
The mining method and total cost of the property, plant and equipment, net of applicable accumulated amortization,
depreciation and impairment as of December 31, 2020 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
Dragline operation with 4 draglines
Dragline operation with 4 draglines
Truck-shovel operation
Dragline operation with 1 dragline
Navajo Mine — Bisti Fuels Company, LLC
Dragline operation with 2 draglines
Consolidated Mining Operations
Red Hills Mine — Mississippi Lignite Mining Company
Dragline operation with 1 dragline
Marshall Mine — Caddo Creek Resources Company, LLC N/A
Eagle Pass Mine — Camino Real Fuels, LLC
NAMining
Other
N/A
(a)
N/A
$
$
$
$
$
$
$
$
$
$
$
81.5
157.6
110.5
—
140.9
—
63.6
—
—
12.0
1.2
(a) During 2020, NAMining operated 32 draglines and one rope shovel at 20 quarries. Of the 32 draglines, 8 are owned by the
Company and 24 are owned by customers. 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.
Predominantly all of Bisti and Demery's machinery and equipment is owned by the customer of the respective mines.
All of the Company’s coal mines are surface mines that are located adjacent to, or nearby, the customer’s power plant, synfuels
plant or activated carbon facility. Overburden, the material between the surface of the land and the coal seam, is removed using
draglines, dozers and/or trucks and shovels, including electric rope shovels. Coal is then extracted and loaded onto haul trucks
using surface miners, excavators, dozers, scrapers, backhoes and other machinery and equipment. Coal is taken to a stockpile or
delivered directly to customers via conveyor or short haul rail. After mining, draglines and/or trucks and shovels are used to
backfill the overburden that was removed at the beginning of the process to allow for site reclamation.
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 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, Caddo Creek, Bisti and Camino Real, where
the customers hold, or held, 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, Demery and Bisti; however, the Company cannot be certain that these third parties will be able to maintain all
such permits in the future.
16
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.
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"); 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. With the exception of the Navajo Nation in New Mexico, which is directly regulated by the Office
of Surface Mining Reclamation and Enforcement ("OSMRE") under their Indian Lands Program, all of the states where the
Company has active coal mining operations have achieved primary control of enforcement through federal authorization under
SMCRA.
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 fee is currently $0.08 per ton on
lignite coal produced and $0.28 per ton on other surface-mined coal.
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 unfunded, with the exception of the final mine closure
costs for the Coyote Creek Mine, which are being funded throughout the production stage.
17
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.
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 November
2020, EPA published a proposed “Revised Cross-State Air Pollution Rule” to address the remand of the CSAPR update. If
promulgated as drafted, this proposed rule will require 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
18
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. SIPs will
be required by July 31, 2021.
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”. 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 vacated the ACE rule. It is
anticipated that the Biden administration will draft a new rule to regulate CO2 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. In addition, in early 2021, the EPA issued an endangerment/significant contribution finding for CO2 emissions from
coal-fired power plants. This endangerment/significant contribution finding is likely to be challenged in the DC Circuit; the
outcome of the legal challenge may have a material adverse effect on the Company’s business, financial condition or results of
operations.
19
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 in June 2020 which modified the types of regulated waters by eliminating
ephemeral streams and certain other isolated wetlands. The new definition is being challenged in court and if the new definition
is overturned, some of the Company's operations could incur additional costs to mitigate streams and wetlands that are not
currently regulated.
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.
20
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 disposed of 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.
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.
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
21
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 lessee's 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 state, and some counties and municipalities, in which the Company operates 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 our royalties
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.
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
22
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
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.
23
FERC also regulates interstate natural gas transportation rates and service conditions and establishes the terms under which our
operators may use interstate natural gas pipeline capacity, which affects the marketing of natural gas that our operators produce,
as well as the revenues our 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 our 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 our 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.
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 allowables 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
24
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, 2021 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. Certain executive officers of the
Company listed below are also executive officers for NACoal.
25
EXECUTIVE OFFICERS OF THE COMPANY
Name
J.C. Butler, Jr.
Age Current Position
60
President and Chief Executive Officer of NACCO (from
September 2017) and President and Chief Executive
Officer of NACoal (from prior to 2016)
Matthew J. Dilluvio
31 Associate Counsel and Assistant Secretary of NACCO
and NACoal (from June 2019)
Elizabeth I. Loveman
51 Vice President and Controller and Principal Financial
Officer (from prior to 2016)
Other Positions
From prior to 2016 to September 2017, Senior Vice
President - Finance, Treasurer and Chief Administrative
Officer of NACCO. From prior to 2016 to September
2017, Assistant Secretary of Hamilton Beach Brands
("HBB") and Kitchen Collection ("KC").
From October 2016 to May 2019, Associate, Sidley
Austin LLP (law firm). From prior to 2016 to September
2016, Associate, White and Case LLP (law firm).
John D. Neumann
45 Vice President, General Counsel and Secretary of
NACCO, Vice President, General Counsel and Secretary
of NACoal (from prior to 2016)
From prior to 2016 to September 2017, Assistant
Secretary of HBB and KC.
Miles B. Haberer
54 Associate General Counsel of NACCO (from prior to
2016), Associate General Counsel, Assistant Secretary of
NACoal (from prior to 2016) and President, North
American Coal Royalty Company (an NACoal
subsidiary) (from prior to 2016)
Sarah E. Fry
45 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 2016 to April 2017, Senior Counsel, Locke
Lord (law firm).
Thomas A. Maxwell
43 Vice President - Financial Planning and Analysis and
Treasurer (from September 2017)
From prior to 2016 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
45
President - MRNA (from March 2017)
Other Positions
From prior to 2016 to February 2017, Environmental
Manager, The Sabine Mining Company (an NACoal
subsidiary)
Philip N. Berry
53
President - NAMining (from prior to 2016)
Eric A. Dale
46 Treasurer and Senior Director, Financial Planning and
Analysis, of NACoal (from January 2017)
From prior to 2016 to November 2016, Vice President of
Financial Planning and Analysis at Westmoreland Coal
Company.
Carroll L. Dewing
64 Vice President - Operations of NACoal (from January
2017)
Andrew B. Hart
42 Controller of NACoal (from September 2019)
From prior to 2016 to December 2016, President, The
Coteau Properties Company (an NACoal subsidiary).
From prior to 2016 to December 2016, Vice President -
North Dakota, Texas and Florida Operations, Human
Resources and External Affairs of NACoal.
From November 2017 to August 2019, Assistant
Controller of NACoal. From prior to 2016 to October
2017, Assistant Controller at Rowan Companies, plc.
Brian M. Larson
37
President - Catapult Mineral Partners, LLC (from May
2019) and Director - Oil and Gas Development (from
April 2019)
From prior to 2016 to March 2019, Engineer at Pioneer
Natural Resources
J. Patrick Sullivan, Jr.
62 Vice President and Chief Financial Officer of NACoal
(from prior to 2016)
26
Item 1A. RISK FACTORS
Risks related to the Coal Mining segment
Termination of or default under long-term mining contracts could materially reduce the Company's profitability.
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. As a result of such activities, the Coal Mining segment's customers could prematurely retire certain coal-
fired generating units. Any customer's premature facility closure could have a material adverse effect on the Company’s
business, financial condition and results of operations.
On May 7, 2020, Great River Energy ("GRE"), Falkirk Mine's customer, and the Company's second largest customer,
announced its intent to retire the Coal Creek Station power plant in the second half of 2022 and modify the Spiritwood Station
power plant to be fueled by natural gas. On November 5, 2020, American Electric Power announced its affiliate, Southwestern
Electric Power Company's (“SWEPCO”), intends to retire the Henry W. Pirkey Plant (the “Pirkey Plant”) in 2023. The Sabine
Mining Company, (“Sabine”) operates the Sabine Mine in Texas and all production from Sabine is delivered to SWEPCO's
Pirkey Plant. See “Item 1. Business — Business Developments" on page 2 in this Form 10-K for further discussion.
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 on
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. If NDDEQ requires significant emissions controls at Coyote Station 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. NDDEQ’s state implementation plan is due to be
submitted to the EPA by July 2021. Preliminary modeling favors minimal additional emissions control measures for all North
Dakota sources. The Company expects NDDEQ to further evaluate additional preliminary control scenarios for regional
visibility modeling in the first quarter of 2021 and prepare a draft state implementation plan available for public comment the
first half of 2021.
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 our coal customers could adversely affect our business, financial
condition, results of operation and cash flows.
For the year ended December 31, 2020, the Coal Mining segment derived approximately 60% of earnings of unconsolidated
operations from two customers, Basin Electric Power Cooperative and GRE. GRE announced its intent to close Coal Creek
station in 2022. 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 Developments" on page 2 in this Form 10-K for
further discussion. Further, in large part as a result of increasing and frequently changing regulation and the realignment of
customers' power generation portfolios that reduce the electric power generated from coal, electric power generators may be
less willing to enter into long-term coal supply contracts. Any shift away from long-term supply contracts could adversely
affect the Company's profitability, cash flows and financial position.
27
Mississippi Lignite Mining Company ("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
$135 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.
MLMC sells lignite at contractually agreed upon prices which are subject to changes in the level of established indices over
time. The price of diesel fuel is heavily-weighted among these indices. As such, a substantial decline in diesel prices could
materially reduce MLMC's profitability, as the decline in revenue will only be partially offset by the effect of lower diesel
prices on production costs.
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 ("IRP"). The
IRP indicates TVA 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. TVA has dispatched Red Hills Power Plant at a lower rate in 2019 and 2020 than in previous years.
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. Southern Company recently publicly disclosed that
while all CGLP lease payments have been paid in full through December 31, 2020, operational and other risks have resulted in
cash liquidity challenges at the Red Hills Power Plant, and based on current forecasts of energy prices in the years following the
expiration of the PPA in 2032, concerns exist regarding the lessee's ability to make the remaining semi-annual lease payments
through the end of the lease term in 2047. During the fourth quarter of 2019, Southern Company concluded that it was no
longer probable that all of the payments would be received over the term of the lease and therefore recognized an impairment
charge to reduce the value of the lease investment. During the second quarter of 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.
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 or 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.
28
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
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 and coal mining industry that affect our customers could also adversely affect the Company. Lower
natural gas prices and increased availability of renewables have 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 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
29
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 16 in this Form 10-K for further discussion.
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") and the Affordable Clean Energy ("ACE") Rule 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, ACE 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 ACE 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 promulgated or proposed 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 16 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, which could significantly reduce the Company's profitability.
Estimates of the Company's recoverable coal reserves involve uncertainties, and inaccuracies in these estimates could
result in lower than expected revenues, higher than expected costs, decreased profitability and asset impairments.
The Company estimates recoverable coal reserves based on engineering and geological data assembled and analyzed by internal
and, less frequently, external engineers and geologists. The Company's estimates as to the quantity and quality of the coal in its
reserves are updated annually to reflect production of coal from the reserves and new drilling, engineering or other data. These
estimates depend upon a variety of factors and assumptions, many of which involve uncertainties and factors beyond the
Company's control, such as geological and mining conditions that may not be fully identified by available exploration data or
that may differ from experience in current operations.
For these reasons, estimates of the recoverable quantities and qualities attributable to any particular group of properties,
classifications of reserves based on risk of recovery and estimates of net cash flows expected from particular reserves may vary
substantially. In addition, coal tonnage recovered from identified reserve areas or properties and revenues and expenditures with
respect to the Company's reserves may vary materially from estimates. Accordingly, the Company's estimates may vary from
30
the actual reserves. Any inaccuracy in the reserve estimates could result in lower than expected revenues, higher than expected
costs, decreased profitability and asset impairments.
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
providing 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 effectively, the Company may not be able to take advantage of market
opportunities. 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.
The Company is subject to the high costs and 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 costs and 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 faces competition from aggregates producers that choose to self-perform mining operations and from other
mining companies.
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.
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. In recent years, a significant portion of the
Minerals Management segment's income has been derived from lease signing bonus and production payments associated with
31
assets in the Utica Shale in Ohio. During 2020, the Company acquired additional mineral interests in the Permian Basin in
Texas. Future royalty-based income is dependent on the number of oil and gas wells being developed and operated on the
Company’s mineral acreage in Ohio and Texas. 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 relating 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 federal 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.
The Company’s producing mineral and royalty interests are located predominantly in the Utica Shale Basin in Ohio and
the Permian Basin in Texas, making the Company vulnerable to risks associated with operating in limited geographic
areas.
The majority of the Company's producing mineral and royalty interests are located predominantly in the Utica Shale Basin in
Ohio and the Permian Basin in Texas. As a result of this concentration, the Company may be disproportionately exposed to the
impact of regional supply and demand factors, pricing differentials, delays or interruptions of production from wells in these
areas caused by governmental regulation, processing or transportation capacity constraints, availability of equipment, facilities,
personnel or services market limitations or interruption of the processing or transportation of crude oil, natural gas or natural
gas liquids. This concentration could result in a relatively greater impact on results of operations than on other companies that
have a more diversified portfolio of mineral and royalty interests. Such impacts could have a material adverse effect on the
Company’s expected royalty income and the Company’s profitability.
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, the Company’s mineral and royalty
interests will decline as those reserves are produced. The future cash flow and results of operations of the Minerals
Management segment are highly dependent on third-party operators’ success in developing the Company’s current and future
mineral and royalty 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 our control; market expectations
about future prices of oil and natural gas; the level of 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
32
natural gas; the level of U.S. domestic production; political and economic conditions in oil producing regions, including the
Middle East, Africa, South America and Russia; 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 by the Company 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;
(v) announcements concerning NACCO or its competitors; (vi) lack of trading liquidity; 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 our 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, contractual limitations 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.
33
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 our 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, 2020, 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, 2020, accounted for the remaining voting power of the Company. As of December 31, 2020, 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 82 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.
General Risk Factors
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.
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.
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 an unsecured
revolving line of credit of up to $150.0 million that expires in August 2022. 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. 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
34
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.
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 action to limit coverage for companies in the coal mining industry,
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 the coal mining industry, costs of insurance may increase
substantially or insurance carriers may decide not to insure the Company in the future. In addition, if the Company makes
significant insurance claims, its ability to obtain future insurance coverage at commercially reasonable rates could be materially
adversely affected. An inability to obtain insurance coverage, significant increases in the premiums or deductibles of insurance
the Company obtains, or losses in excess of its liability insurance coverage limits, which may go down in the future, could have
a material adverse effect on the Company's operating results and financial condition.
Increasing scrutiny and changing expectations with respect to the Company’s environmental, social and governance
practices may impose additional costs on the Company or expose the Company to new or additional risks.
Companies across all industries are facing increasing scrutiny from stakeholders related to their environmental, social and
governance (“ESG”) practices. 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 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’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; deliver inventory on a timely basis; and maintain cost-efficient operations. Despite the
Company's efforts, the Company’s information technology systems may be vulnerable, from time to time, to damage or
interruption from computer viruses, power outages, third-party intrusions and other technical malfunctions.
35
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 to 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, including quarantines,
"shelter in place" and "stay at home" orders, travel restrictions, business curtailments, school closures, and other measures.
Throughout the pandemic, the Company has continued to operate as an essential business because it supports critical
infrastructure industries, as defined by the U.S. Department of Homeland Security. 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, and
the timing for proven treatments and availability of vaccines for COVID-19. 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.
36
Item 1B. UNRESOLVED STAFF COMMENTS
None.
Item 2. PROPERTIES
NACCO leases office space in Mayfield Heights, Ohio, a suburb of Cleveland, Ohio, which serves as its corporate
headquarters.
NACoal leases its corporate headquarters office space in Plano, Texas.
NAMining leases office and warehouse space in Medley, Florida.
Proven and probable coal reserves and deposits are estimated at approximately 1.9 billion tons (including the Unconsolidated
Subsidiaries), all of which are lignite coal deposits, except for approximately 58.0 million tons of bituminous coal. Reserves are
estimates of quantities of coal, made by the Company's geological and engineering staff, which are considered mineable in the
future using existing operating methods. Developed reserves are those which have been allocated to mines which are in
operation; all other reserves are classified as undeveloped. Information concerning mine type, reserve data and coal quality
characteristics are set forth on the table on pages 9 and 10 under “Item 1. Business — SEC Industry Guide 7 Information .”
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.
37
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, 2020, there were 705 Class A common stockholders of record and 132 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, 2020
November 1 to 30, 2020
December 1 to 31, 2020
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 6, 2019, the Company's Board of Directors approved a stock purchase program ("2019 Stock Repurchase
Program") providing for the purchase of up to $25.0 million of the Company’s outstanding Class A common stock
through December 31, 2021. 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.
38
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, through a portfolio of mining and natural resources businesses, operates under three
business segments: Coal Mining, North American Mining ("NAMining") and Minerals Management. The Coal Mining
segment operates surface coal mines under long-term contracts with power generation companies and an activated carbon
producer pursuant to a service-based business model. The NAMining segment provides value-added contract mining and other
services for producers of aggregates, lithium and other minerals. The Minerals Management segment acquires and promotes
the development of oil, gas and coal mineral interests, generating income primarily from royalty-based lease payments from
third parties. In addition, the Company has a business providing stream and wetland mitigation solutions.
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 of North America® (“MRNA”) and Bellaire Corporation
(“Bellaire”). MRNA generates and sells stream 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.
As of January 1, 2020, the Company retrospectively changed its computation of segment operating profit to reclassify certain
expenses, primarily related to executive and board compensation. These expenses are now included in unallocated items. The
change in segment reporting reflected a decision to evaluate the financial performance of the Company’s segments excluding
executive and board compensation. All prior period segment information has been reclassified to conform to the new
presentation. This segment reporting change has no impact on consolidated operating results.
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.
39
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)
Accounting for Asset Retirement Obligations: 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. Under certain federal and state regulations, the Company
is required to reclaim land disturbed as a result of mining. The Company determined the amounts of these obligations based on
cost estimates, adjusted for inflation, projected to the estimated closure dates, and then discounted using a credit-adjusted risk-
free interest rate. Changes in any of these estimates could materially change the Company's estimates for these asset retirement
obligations causing a related increase or decrease in reported net operating results in the period of change in the estimate. The
accretion of the liability is being recognized over the estimated life of each individual asset retirement obligation. The
Company has capitalized an asset’s retirement cost as part of the cost of the related long-lived asset. These capitalized amounts
are subsequently amortized to expense using a systematic and rational method.
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
Company determined the amounts of these obligations based on cost estimates, adjusted for inflation, and then discounted
using a credit-adjusted risk-free interest rate. The accretion of the liability is recognized over the estimated life of the asset
retirement obligation. Since Bellaire's properties are no longer active operations, no associated asset has been capitalized.
Changes in any of these estimates could materially change the Company's estimates for these asset retirement obligations
causing a related increase or decrease in reported net operating income in the period of change in the estimate. See Note 7 to
the Consolidated Financial Statements in this Form 10-K for further discussion of the Company's asset retirement obligations.
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
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 $135 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
40
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)
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.
41
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
Income from other unconsolidated affiliates
Closed mine obligations
Gain on equity securities
Other, net
Other income, net
Income before income tax (benefit) provision
Income tax (benefit) provision
Net income
Effective income tax rate
2020
2019
$ 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)
(239)
1,641
(1,226)
(1,140)
(810)
$ 68,701
42,823
30,119
790
(1,443)
$ 140,990
$ 34,120
(564)
25,721
(20,713)
256
$ 38,820
872
(3,616)
(1,300)
1,537
(1,545)
(527)
(4,579)
14,258
(535)
$ 14,793
43,399
3,767
$ 39,632
(3.8) %
8.7 %
The components of the change in revenues and operating profit are discussed below in "Segment Results."
Other (income) expense, net
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 2019, the Company received payment of $2.7 million from NACC India's customer, of which
$1.4 million related to past invoices and has been reported on the line Other, net, and $1.3 million represented interest income
and has been reported on the line Interest income. During 2020, the Company received an additional payment of $1.0 million
from NACC India's customer which has been reported on the line, Other, net. Both of these lines are in the Other (income)
expense section of the Consolidated Statements of Operations. The Company does not expect to receive any additional
payments from NACC India’s customer.
Interest expense increased $0.5 million due to higher average borrowings during 2020 compared with 2019.
42
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)
Interest income decreased $2.4 million primarily due to the interest income related to the NACC India customer payment the
Company received in 2019 and lower interest rates on invested cash during 2020 compared with 2019.
Income from other unconsolidated affiliates represents the financial results of NoDak. NoDak operated and maintained a coal
drying system at a customer’s power plant. The NoDak contract expired on January 31, 2020, resulting in a decrease of $1.1
million in Income from other unconsolidated affiliates during 2020 compared with 2019.
Gain on equity securities represents changes in the market price of invested assets reported at fair value. See Note 9 to the
Consolidated Financial Statements in this Form 10-K for further discussion of the Mine Water Treatment Trust.
Other, net, increased $0.6 million primarily due to the absence of $0.9 million in settlement expense for the Combined Defined
Benefit Plan recognized during 2019. See Note 14 to the Consolidated Financial Statements in this Form 10-K for further
discussion of the Company's pension and postretirement expense.
Income Taxes
The Company recorded an 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%), compared to income tax expense of $3.8 million on income before income tax of $43.4
million, or 8.7%, for the year ended December 31, 2019. 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 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. Discrete tax items in the year ended December 31, 2019 were a benefit of $2.5
million primarily resulting from changes in prior year estimates and the effective settlement of certain discrete tax items from
on-going examinations.
The Company’s effective income tax rate, excluding the CARES Act and discrete items, was (22.0%) and 14.5% for the years
ended December 31, 2020 and 2019, respectively. The effective income tax rate differs from the U.S. federal statutory rate
primarily due to the benefit from percentage depletion. The benefit of percentage depletion is not directly related to the amount
of pre-tax income recorded in a period. Accordingly, as a result of the $29.1 million reduction in income before income tax in
2020 compared to 2019, the proportional effect of the benefit from percentage depletion on the effective income tax rate in
2020 resulted in a significantly lower effective tax rate in 2020 compared to 2019.
See Note 13 to the Consolidated Financial Statements in this Form 10-K for further discussion of the Company's income taxes.
43
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)
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 (used by) provided by 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
2020
2019
Change
$
14,793 $
39,632 $
(24,839)
18,114
7,517
3,078
16,240
8,698
4,924
(269)
(206)
1,973
8,359
—
—
(3,452)
(52,599)
(7,071)
(9,433)
(2,486)
52,784
1,874
(1,181)
(1,846)
(63)
1,973
8,359
3,619
(43,166)
(55,270)
(44,368)
(24,664)
(19,704)
571
(2,187)
4,572
(170)
(4,001)
(2,017)
(45,984)
(20,262)
(25,722)
Cash flow before financing activities
$
(48,470) $
32,522 $
(80,992)
The $55.3 million decrease in net cash provided by operating activities was primarily the result of unfavorable working capital
changes and the decrease in net income, partially offset by impairment charges. Working capital changes primarily included:
•
•
•
Increased payments made under deferred compensation and long-term incentive compensation plans during 2020
compared with 2019.
An increase in Accounts receivables during 2020 compared to a decrease during 2019. The large decrease in 2019
was primarily due to the timing of customer requirements at MLMC.
A decrease in Accounts payable during 2020 compared to an increase during 2019 due to a change in timing.
The increase in net cash used for investing activities was primarily attributable to $14.2 million in acquisitions of mineral and
royalty interests at the Minerals Management segment during 2020 compared with none during 2019.
Financing activities:
Net additions to long-term debt and revolving credit agreements
Cash dividends paid
Other
20,073 $
13,258 $
(5,375)
(670)
(5,132)
(3,013)
Net cash provided by financing activities
$
14,028 $
5,113 $
6,815
(243)
2,343
8,915
2020
2019
Change
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)
The change in net cash provided by financing activities was primarily due to increased borrowings during 2020 compared with
2019.
Financing Activities
Financing arrangements are obtained and maintained at the subsidiary level. 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 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.
NACoal has an unsecured revolving line of credit of up to $150.0 million (the “NACoal Facility”) that expires in August 2022.
Borrowings outstanding under the NACoal Facility were $30.0 million at December 31, 2020. At December 31, 2020, the
excess availability under the NACoal Facility was $117.0 million, which reflects a reduction for outstanding letters of credit of
$3.0 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, 2020, for base rate and LIBOR
loans were 0.75% and 1.75%, respectively. The NACoal Facility has a commitment fee which is based upon achieving various
levels of debt to EBITDA ratios. The commitment fee was 0.30% on the unused commitment at December 31, 2020. The
weighted average interest rate applicable to the NACoal Facility at December 31, 2020 was 1.88% including the floating rate
margin.
The NACoal Facility contains restrictive covenants, which require, among other things, NACoal to maintain a maximum debt
to EBITDA ratio of 3.00 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 2.00 to 1.00, or if greater than 2.00 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, 2020, NACoal was in compliance with all financial covenants in the NACoal Facility.
NACoal’s variable interest payments are calculated based upon NACoal’s anticipated payment schedule and the December 31,
2020 base rate and applicable margins, as defined in the NACoal Facility. A 1/8% increase in the base rate would increase
NACoal’s estimated total annual interest payments on the NACoal Facility by less than $0.1 million.
Expenditures for property, plant and equipment and mineral interests
Following is a table which summarizes actual and planned expenditures (in millions):
NACCO
Planned
2021
Actual
2020
Actual
2019
$
46.6 $
44.4 $
24.7
Planned expenditures for 2021 are expected to be approximately $46 million, primarily consisting of $27 million in the Coal
Mining segment, $10 million in the Minerals Management segment and $9 million in the NAMining segment.
In the Coal Mining segment, elevated levels of expected capital expenditures through 2021 are primarily related to spending at
MLMC as it develops a new mine area. In the Minerals Management segment, expected expenditures in 2021 are primarily for
the acquisition of mineral interests. In the NAMining segment, expected capital expenditures in 2021 are primarily for the
acquisition, relocation and refurbishment of draglines.
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)
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
2020
2019
Change
$ 88,450
$ 122,892
$
(34,442)
244,907
174,465
35,330
37,902
368,687
335,259
(46,465)
(21,598)
(24,943)
(20,924)
70,442
(2,572)
33,428
(21,522)
(674)
$ 300,624
$ 289,392
$
11,232
13 %
8 %
5 %
The increase in other net tangible assets was primarily due to increases in Property, plant and equipment as well as payments
made for deferred compensation and accrued incentive compensation during 2020.
Contractual Obligations, Contingent Liabilities and Commitments
NACCO adopted ASU 2016-02, “Leases (Topic 842)," on January 1, 2019. ASC 842 required a lessee to recognize a right-of-
use asset and a corresponding lease liability for substantially all leases. See Note 10 to the Consolidated Financial Statements
in this Form 10-K for further information on the Company's leases.
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 2021. 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
in 2021 and approximately $0.5 million per year from 2022 through 2030. Benefit payments beyond that time cannot currently
be estimated. All other pension benefit payments are made from assets of the pension plan. NACCO also expects to make
payments related to its other postretirement plans of approximately $0.2 million per year from 2021 through 2030. Benefit
payments beyond that time cannot currently be estimated.
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 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.
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
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)
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
Tons of coal delivered by the Coal Mining segment were as follows for the years ended December 31 (in millions):
Unconsolidated mines
Consolidated mines
Total tons delivered
Total coal reserves were as follows at December 31:
Unconsolidated mines
Consolidated mines
Total coal reserves
2020
2019
28.5
2.5
31.0
32.0
2.6
34.6
2020(1)
2019(1)
(in billions of tons)
1.0
0.9
1.9
1.0
1.0
2.0
(1)Amount includes 0.1 billion of coal reserves owned or controlled by customers as of both December 31, 2020 and December
31, 2019. The Company conducts activities to extract these customer-owned and controlled reserves.
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)
Selling, general and administrative expenses
Amortization of intangible assets
Gain on sale of assets
Operating profit
2020
2019
$
72,088 $
70,452
1,636
56,584
30,216
2,572
68,701
65,430
3,271
60,678
27,394
2,614
(4)
(179)
$
25,436 $
34,120
(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.
2020 Compared with 2019
Revenues increased 4.9% in 2020 compared with 2019 primarily due to an increase in price per ton attributable to
reimbursable costs at MLMC. The sales price at MLMC is index-based and includes adjustments for coal quality and
reimbursable costs.
Also contributing to the increase is reclamation revenue from Caddo Creek. On September 30, 2020, Caddo Creek's customer,
a division of Cabot Corporation, entered into a long-term supply agreement with a subsidiary of Advanced Emissions
Solutions (“AES”) as well as an agreement for the sale of the Marshall Mine, operated by Caddo Creek, to a subsidiary of
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)
AES. AES announced its intent to close the Marshall Mine. Caddo Creek entered into a contract with a subsidiary of AES to
perform the required mine reclamation. As a result of these changes, Caddo Creek financial results are now consolidated
within the Coal Mining segment.
The following table identifies the components of change in operating profit for 2020 compared with 2019:
2019
Increase (decrease) from:
Earnings of unconsolidated operations
MLMC 's inventory impairment charge
Gross profit, excluding revisions to Centennial's asset retirement obligation and MLMC's inventory
impairment charge
Voluntary separation program ("VSP") charge
Selling, general and administrative expenses, excluding VSP charge
Net gain on sale of assets
Revisions to Centennial's asset retirement obligation
Amortization of intangibles
2020
Operating Profit
34,120
$
(4,094)
(1,973)
(1,741)
(1,475)
(1,347)
(175)
2,079
42
25,436
$
Operating profit decreased $8.7 million in 2020 compared with 2019. The change in operating profit was primarily due to:
•
•
•
•
A decrease in earnings of unconsolidated operations, mainly due to a reduction in tons delivered as a result of
decreases in customer demand and the termination of the Camino Real contract mining agreement during 2020.
A $2.0 million inventory impairment charge at MLMC as mining costs exceeded net realizable value.
A reduction in gross profit due to wind-down and employee-related expenses at Camino Real.
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 Coal Mining
segment recorded a charge of $1.5 million related to one-time termination benefits.
• An increase in selling, general and administrative expenses due to a $1.1 million asset impairment charge, higher
professional fees, outside service fees and insurance costs, partially offset by lower employee-related expenses.
•
The favorable net change in Centennial's asset retirement obligation is attributable to the absence of a $2.5 million
unfavorable revision that occurred during 2019, partially offset by a $0.4 million unfavorable revision that occurred
during 2020. See Note 7 to the Consolidated Financial Statements in this Form 10-K for further discussion of the
Company's asset retirement obligations.
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)
NORTH AMERICAN MINING ("NAMining") SEGMENT
FINANCIAL REVIEW
Tons of limestone delivered by the NAMining segment were as follows for the years ended December 31 (in millions):
Unconsolidated operations
Consolidated operations
Total tons delivered
2020
2019
9.4
36.5
45.9
8.3
36.4
44.7
The results of operations for the NAMining segment were as follows for the years ended December 31:
Revenues
Cost of sales
Gross profit
Earnings of unconsolidated operations(a)
Selling, general and administrative expenses
Gain on sale of assets
Operating profit (loss)
2020
2019
$
42,392 $
39,266
3,126
3,619
5,138
(265)
$
1,872 $
42,823
41,698
1,125
3,205
4,921
(27)
(564)
(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.
2020 Compared with 2019
Revenues decreased 1.0% in 2020 compared with 2019, primarily due to lower reimbursed costs, which have an offsetting
amount in cost of goods sold and have no impact on operating profit. The decrease was partially offset by favorable changes in
the mix of customer requirements and work related to the Thacker Pass lithium project.
The following table identifies the components of change in operating profit (loss) for 2020 compared with 2019.
2019
Increase (decrease) from:
Gross profit
Earnings of unconsolidated operations
Net gain on sale of assets
Selling, general and administrative expenses
2020
Operating Profit
(Loss)
$
(564)
2,001
414
238
(217)
1,872
$
NAMining reported operating profit of $1.9 million in 2020 compared with an operating loss of $0.6 million in 2019. The
change is primarily due to an increase in gross profit and in earnings of unconsolidated operations. Both variances are due to
changes in the mix of customer requirements.
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)
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
Operating profit
2020 Compared with 2019
2020
2019
$
14,721 $
30,119
2,342
12,379
8,886
3,465
26,654
933
$
3,493 $
25,721
Revenues and operating profit decreased in 2020 compared with 2019 as 2019 included significant royalty income generated
by a large number of new gas wells put into commission in Ohio during 2018 and early 2019. These wells are operated by
third parties to extract natural gas from the Company's Ohio Utica shale mineral reserves. Since new wells have high initial
production rates and follow a natural decline before settling into relatively stable, long-term production, royalty income in
2020 decreased substantially from 2019 levels. Lower commodity prices in 2020 compared with 2019 also contributed to the
reduction in revenues and operating profit. The increase in selling, general and administrative expenses is due to a $7.3 million
asset impairment charge during 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.
UNALLOCATED ITEMS AND ELIMINATIONS
FINANCIAL REVIEW
Unallocated Items and Eliminations were as follows for the years ended December 31:
Operating loss
2020 Compared with 2019
2020
2019
$
(17,353) $
(20,457)
The $3.1 million decrease in operating loss during 2020 compared with 2019 was primarily due to lower employee-related
expenses.
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 - 2021
In 2021, the Company expects coal deliveries to be comparable to 2020 based on current expectations of customer
requirements.
Coal Mining operating profit in 2021 is expected to decrease significantly from 2020. This decrease is primarily attributable to
substantially lower earnings expected at MLMC and reduced earnings at the unconsolidated Coal Mining operations. MLMC
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)
earnings are expected to be lower as a result of an anticipated increase in the cost per ton of coal delivered in 2021 compared
with 2020, due in part to an increase in depreciation expense associated with development of a new mine area. The anticipated
reduction in earnings at the unconsolidated Coal Mining operations is expected to be mainly driven by a reduction in fee-based
earnings at the Liberty Mine, as the scope of final mine reclamation activities is reduced. Lower operating profit is expected to
be partially offset by a decrease in operating expenses primarily due to lower employee-related costs resulting from the 2020
voluntary separation program partially offset by higher insurance expense.
Changes in customer power plant dispatch, including changes related to natural gas price fluctuations and the continued
increase in renewable generation, particularly wind, could reduce customer demand below anticipated levels, which could
further unfavorably affect the Company’s 2021 outlook.
In May 2020, GRE, Falkirk Mine's customer and the Company's second largest customer, announced its intent to retire the
Coal Creek Station power plant in the second half of 2022. GRE is willing to consider opportunities to sell Coal Creek Station,
and NACCO is actively engaged in the exploration of options that could, if successful, allow for transfer of ownership of the
power plant to one or more third parties, which would preserve jobs at both Coal Creek Station and the Falkirk Mine. Falkirk
Mine is the sole supplier of lignite coal to Coal Creek Station pursuant to a long-term contract. The terms of the contract
between the Company and GRE specify that GRE is responsible for all costs related to mine closure, including but not limited
to, final mine reclamation costs, post-retirement medical benefits and pension costs with respect to Falkirk employees. This
closure is not expected to affect 2021 results.
The owner of the power plant served by the Company's Sabine Mine in Texas intends to retire the power plant in 2023. The
Sabine Mine contributed approximately $3.9 million to Earnings from Unconsolidated Operations in 2020. The terms of the
contract between the Company and the customer specify that the customer is responsible for all costs related to mine closure,
including but not limited to, final mine reclamation costs, post-retirement medical benefits and pension costs with respect to
Sabine employees.
The closure of the power plants that are served by the Falkirk and Sabine Mines would have a material adverse effect on the
future Earnings of unconsolidated operations of the Coal Mining segment and on the long-term earnings and cash flows of
NACCO.
Capital expenditures are expected to be approximately $27 million in 2021. The elevated levels of capital expenditures in the
Coal Mining segment from 2019 through 2021 relate to the development of a new mine area at MLMC. These increased
capital expenditures will result in higher depreciation that will unfavorably affect operating profit in future periods. Capital
expenditures for MLMC are expected to return to lower levels beginning in 2022 and continue through 2032, the end of the
current contract term.
NAMining Outlook
In 2021, NAMining expects full year operating profit to increase moderately over 2020 with its existing customer contracts.
NAMining is pursuing a number of growth initiatives that if successful would be accretive to future earnings.
Capital expenditures are expected to be approximately $9 million for the 2021 full year primarily for the acquisition,
relocation and refurbishment of draglines.
In 2019, NAMining's subsidiary, Sawtooth Mining, LLC, entered into a mining 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). In January 2021, Thacker Pass received a Record of Decision from the U.S.
Bureau of Land Management for the Thacker Pass project following the completion of the National Environmental Policy Act
Process. This decision represents an important milestone in the development and the permitting of the Thacker Pass project.
More permitting decisions are expected later in 2021 with production expected to begin in the second half of 2022.
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 and, to a lesser extent, oil, natural gas liquids and coal, extracted primarily by third
parties. Excluding the impact of the $6.7 million write-off taken in 2020, operating profit in the Minerals Management
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)
segment is expected to be down substantially in 2021 from 2020. This decrease is primarily related to a reduction in royalty
income from existing Ohio mineral and royalty assets as a result of expected lower natural gas prices, fewer expected new
wells in Ohio, lower commodity prices and the natural production decline that occurs early in the life of a well. Another
sustained decline in natural gas prices could unfavorably affect the Company’s outlook.
Decline rates for individual wells can vary due to factors like well depth, well length, formation pressure and facility design. In
addition, 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 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.
In 2020, the Minerals Management segment acquired mineral and royalty interests for approximately 65.5 thousand gross
acres and 1.2 thousand net royalty acres in the Permian Basin in Texas for a total purchase price of approximately $14.2
million. The acquired interests 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 oil-rich basins offering diversification from the
Company’s legacy mineral interests in predominately natural gas-rich basins. Including the 2020 acquisitions, total mineral
and royalty interests include approximately 109.2 thousand gross acres and 58.1 thousand net royalty acres. Minerals
Management is targeting additional investments in mineral and royalty interests of approximately $10 million in 2021. These
investments are expected to be accretive to earnings, but each investment's contribution to earnings is dependent on the
characteristics of each investment, including the size and type of interests acquired and the stage and timing of mineral
development.
Consolidated 2021 Outlook
While the Company expects consolidated net income in 2021 to decrease significantly from 2020, management still continues
to view the long-term business outlook positively because of a strong pipeline of potential new projects. The COVID-19
pandemic slowed certain business development initiatives in 2020, but the outlook for growth in the NAMining and Minerals
Management segments and in the Company's Mitigation Resources of North America® business remains strong. Excluding the
favorable impact of potential business development activities, the Company expects substantially lower pre-tax earnings as a
result of lower operating profit, an anticipated increase in interest expense and a reduction in interest income. These lower pre-
tax results are expected to be partially offset by an increase in the benefit from income taxes primarily due to the benefit from
percentage depletion at certain of the Company's mining operations. Pre-tax income and net income are expected to be higher
in the second half of 2021 than in the first half of 2021, primarily due to current expectations on the timing of customer
requirements in the Coal Mining segment.
In light of ongoing regulatory, economic and public opinion challenges facing the coal-fired power generation industry, the
Company commenced a voluntary separation program for certain corporate employees in the 2020 fourth quarter. The
program was substantially completed by December 31, 2020. Estimated net benefits from this voluntary separation program
are expected to be between $1.5 and $2.5 million annually beginning in 2021. As a result of this program and natural attrition,
the number of headquarters employees was reduced by approximately 25%.
The Company’s cash flow before financing activities varies with changes in customer demand, particularly in the Coal Mining
segment, as well as changes in earnings of the Minerals Management segment, working capital changes, capital expenditures,
investments in royalty and mineral interests and changes in income taxes, as well as other factors. Cash flow before financing
activities in 2020 included a significant use of cash related to changes in working capital, capital expenditures and the
acquisition of mineral royalty interests. The Company anticipates positive cash flow before financing activities in 2021 but at a
level still below the cash generated in 2019. Consolidated capital expenditures are expected to be approximately $46 million in
2021.
Significant uncertainties remain regarding the COVID-19 pandemic. The extent to which COVID-19 impacts the Company
going forward will depend on numerous factors, including but not limited to the extent of new outbreaks, the extent to which
additional stay-at-home orders may be imposed, the nature of the government public health guidelines and the public's
adherence to those guidelines, the success of businesses reopening fully, the timing for proven treatments and the availability
of vaccines for COVID-19. While the Company's existing mining operations to date have not been materially affected by the
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)
pandemic, future developments, which are highly uncertain and unpredictable, could significantly and rapidly cause a
deterioration in the Company’s results, supply chain channels and customer demand.
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.
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. In addition, NAMining is pursuing opportunities to provide
comprehensive mining services to operate entire mines when appropriate, as is the case at the new lithium project in Nevada.
The Minerals Management segment continues its efforts to grow and diversify by pursuing acquisitions of additional mineral
and royalty interests in the United States, in what the Company believes is a buyer-friendly market. Once mineral and royalty
interests have been acquired, the Minerals Management segment will benefit from the continued development of its mineral
properties without additional capital investment. 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.
MRNA 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 opportunity for growth and diversification in an
industry where the Company has substantial knowledge and expertise and a strong reputation. The MRNA business has
achieved several successes and is positioned for additional growth.
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.
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. Low natural gas prices and growth in renewable energy sources, such as wind and
solar, are likely to continue to unfavorably affect the amount of electricity dispatched from coal-fired power plants. 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 while it grows and diversifies without unnecessary
risk, which will allow for strategic growth and increased free cash flow to re-invest in 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.
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)
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 a long-term
mining contract, or a customer default under a contract, (2) the impact of the COVID-19 pandemic, (3) a significant reduction
in purchases by the Company's customers, including 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) changes in
tax laws or regulatory requirements, including changes in mining or power plant emission regulations and health, safety or
environmental legislation, (5) the ability of the Company to access credit in the current economic environment, or obtain
financing at reasonable rates, or at all, as a result of current market sentiment for fossil fuels, (6) failure to obtain adequate
insurance coverages at reasonable rates, (7) changes in costs related to geological and geotechnical conditions, repairs and
maintenance, new equipment and replacement parts, fuel or other similar items, (8) regulatory actions, changes in mining
permit requirements or delays in obtaining mining permits that could affect deliveries to customers, (9) weather conditions,
extended power plant outages, liquidity events or other events that would change the level of customers' coal or aggregates
requirements, (10) weather or equipment problems that could affect deliveries to customers, (11) 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, (12) changes in
the costs to reclaim mining areas, (13) costs to pursue and develop new mining and value-added service opportunities, (14)
delays or reductions in coal or aggregates deliveries, (15) changes in the prices of hydrocarbons, particularly diesel fuel,
natural gas and oil, (16) the ability to successfully evaluate investments and achieve intended financial results in new business
and growth initiatives, (17) the effects of receiving low sustainability scores which could result in the exclusion of the
Company's securities from consideration by certain investment funds, and (18) 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.
54
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, 2020 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, 2020. The Company's effectiveness of internal control over financial reporting as of
December 31, 2020 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 2020, that have materially affected, or are reasonably likely to materially affect, the
Company's internal control over financial reporting.
Item 9B. OTHER INFORMATION
None.
55
PART III
Item 10. DIRECTORS, EXECUTIVE OFFICERS AND CORPORATE GOVERNANCE
Information with respect to Directors of the Company will be set forth in the 2021 Proxy Statement under the subheadings “Part
III — Proposals To Be Voted On At The 2021 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
2021 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 2021 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 2021 Proxy Statement under the headings “Part II —
Executive Compensation Information” and “Part III — Proposals To Be Voted On At The 2021 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 2021 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 2021 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 2021 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 2021 Proxy Statement under the
heading “Part III — Proposals To Be Voted On At The 2021 Annual Meeting — Proposal 4 — Ratification of the Appointment
of Company's Independent Registered Public Accounting Firm,” which information is incorporated herein by reference.
56
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-39 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
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.
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.
57
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
10.18
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. 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.
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.
Transfer Restriction Agreement, dated as of September 29, 2017, by and among the Issuer, NACCO and the
signatories thereto, is incorporated by reference to Exhibit 2 of Hamilton Beach Brands Holding Company's
General statement of acquisition of beneficial ownership on Form SC 13D, filed on October 6, 2017, 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.
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.+
58
Exhibit
Number
10.19
10.20
10.21
10.22
10.23
10.24
10.25
10.26
10.27
10.28
10.29
10.30
10.31
10.32
10.33
Exhibit Description
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.
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.
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.
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.
59
Exhibit
Number
10.34
10.35
10.36
10.37
10.38
10.39
10.40
10.41
10.42*
10.43*
10.44*
10.45*
10.46
10.47
10.48
Exhibit Description
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.++
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.
60
(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)
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.
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)
*
**
+
++
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.
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".
61
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 3, 2021
62
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 3, 2021
Vice President and Controller (principal financial
and accounting officer)
March 3, 2021
Director
Director
Director
Director
Director
Director
Director
Director
Director
Director
Director
March 3, 2021
March 3, 2021
March 3, 2021
March 3, 2021
March 3, 2021
March 3, 2021
March 3, 2021
March 3, 2021
March 3, 2021
March 3, 2021
March 3, 2021
* 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 3, 2021
63
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, 2020
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 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, 2020.
Report of Ernst & Young LLP, Independent Registered Public Accounting Firm on Internal Control Over Financial
Reporting — As of December 31, 2020.
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 Stockholders and 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, 2020 and 2019, 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, 2020 and 2019, 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, 2020, 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 3, 2021 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 account or disclosure to which it relates.
F-3
Asset Retirement Obligations Liability
Description of the Matter
How We Addressed the
Matter in Our Audit
At December 31, 2020, the Company’s aggregate asset retirement obligations were
approximately $41.7 million. As discussed in Note 7 to consolidated financial statements, 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. The Company reviewed its asset retirement obligations at each mine site and made
necessary adjustments for permit changes and for revisions of estimates of the timing and
extent of reclamation activities and cost estimates.
Management’s estimate involves a high degree of subjectivity and auditing the significant
assumptions utilized by management in estimating the fair value of the liability requires
judgement. 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 regulations
and assumptions regarding equipment productivity.
We obtained an understanding, evaluated and tested the design and operating effectiveness of
the controls surrounding the Company’s processes to determine the fair value of the asset
retirement obligations. This included controls related to estimating the future cash
expenditures to reclaim each mine site and other key assumptions underlying the calculation
of the obligation.
To test the asset retirement obligation, our audit procedures included, among other things,
evaluating the methodology used, the significant assumptions referenced above, and the
underlying data used by the Company. We evaluated the credit-adjusted risk-free rate applied
to calculate the net present value of the obligation as compared to observable market data. We
involved our mine reclamation specialists to assist in testing the significant assumptions.
Specifically, we evaluated the estimates of the life of mines the Company used in calculating
its significant reclamation obligations based on the known mineral reserves and expected
production, and consideration of the estimate of disturbed acreage through inspection of
permits, approved site restoration plans and restoration area schematics. We assessed the
identification of reclamation activities by the Company’s mine engineers by comparison to
environmental laws and regulations and the likely cost of the reclamation activities as
determined by the Company’s mine engineers compared with historical amounts, published
pricing data and other publicly available information. We recalculated the reclamation
obligations using management’s model.
/s/ Ernst & Young LLP
We have served as the Company’s auditor since 2002.
Cleveland, Ohio
March 3, 2021
F-4
Report of Independent Registered Public Accounting Firm
To the Stockholders and 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, 2020,
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, 2020,
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 2020 consolidated financial statements of the Company and our report dated March 3, 2021 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 3, 2021
F-5
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
Year Ended December 31
2020
2019
(In thousands, except per share data)
$
128,432 $
111,463
16,969
60,203
53,062
2,572
(269)
8,359
63,724
13,448
1,354
(1,200)
(239)
1,641
(1,226)
(1,140)
(810)
14,258
(535)
14,793 $
2.11 $
2.10 $
7,026
7,057
$
$
$
140,990
109,862
31,128
63,883
53,783
2,614
(206)
—
56,191
38,820
872
(3,616)
(1,300)
1,537
(1,545)
(527)
(4,579)
43,399
3,767
39,632
5.68
5.66
6,974
7,007
Revenues
Cost of sales
Gross profit
Earnings of unconsolidated operations
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
Income from other unconsolidated affiliates
Closed mine obligations
Gain on equity securities
Other, net
Income before income tax (benefit) provision
Income tax (benefit) provision
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 $213 tax benefit and
$226 tax expense in 2020 and 2019, respectively
Pension settlement, net of $202 tax benefit in 2019
Reclassification of pension and postretirement adjustments into earnings, net of $129
and $90 tax benefit in 2020 and 2019, respectively
Total other comprehensive income
Comprehensive income
See notes to the Consolidated Financial Statements.
Year Ended December 31
2020
2019
(In thousands)
$
14,793 $
39,632
(697)
—
435
(262)
$
14,531 $
758
671
845
2,274
41,906
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 expenses and other
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 compensation
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, 5,489,615 shares outstanding (2019 - 5,397,458 shares outstanding)
Class B, par value $1 per share, convertible into Class A on a one-for-one basis, 1,568,210 shares
outstanding (2019 - 1,568,670 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
2020
2019
(In thousands, except share data)
$
$
$
$
88,450 $
18,894
4,764
47,551
17,615
10,872
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
—
8,224
52,257
24,353
11,196
39,888
8,838
17,550
9,413
12,060
175,555
122,892
15,444
6,411
40,465
8,928
6,528
200,668
138,061
37,902
24,611
11,398
32,133
444,773
9,374
577
7,000
795
2,285
19,583
13,465
8,887
61,966
17,148
12,448
34,574
8,807
12,338
1,912
6,188
155,381
5,490
5,397
1,568
10,895
294,270
(11,599)
300,624
476,179 $
1,569
8,911
284,852
(11,337)
289,392
444,773
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 (used for) provided by 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 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 provided by financing activities
Cash and Cash Equivalents
Total (decrease) increase 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
2020
2019
(In thousands)
$
14,793 $
39,632
18,114
16,240
334
7,517
3,078
(269)
1,973
8,359
334
8,698
4,924
(206)
—
—
(3,786)
(7,405)
20
42
(9,361)
(2,582)
(10,622)
(10,790)
(19,306)
(2,486)
(30,187)
(14,181)
571
(2,000)
(187)
1,903
8,221
(9,256)
1,432
(388)
(5,447)
(5,898)
52,784
(24,664)
—
4,572
—
(170)
(45,984)
(20,262)
14,000
7,427
(1,354)
(5,375)
(1,002)
332
14,028
12,000
2,000
(742)
(5,132)
(3,010)
(3)
5,113
(34,442)
122,892
37,635
85,257
$
88,450 $
122,892
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
Income (Loss)
Total
Stockholders'
Equity
$
Balance, January 1, 2019
Stock-based compensation
Purchase of treasury shares
Net income
Cash dividends on Class A and Class B common stock:
$0.7350 per share
Current period other comprehensive income, net of tax
Pension settlement, net of tax
Reclassification adjustment to net income, net of tax
Balance, December 31, 2019
Stock-based compensation
Purchase of treasury shares
Conversion of Class B to Class A 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
$
$
5,352 $
117
(72)
—
—
—
—
—
5,397 $
124
(32)
1
—
—
—
—
5,490 $
(In thousands, except per share data)
7,042 $ 250,352 $
—
4,807
—
(2,938)
39,632
—
1,569 $
—
—
—
—
—
—
—
1,569 $
—
—
(1)
—
—
—
—
1,568 $
—
—
—
—
(5,132)
—
—
—
8,911 $ 284,852 $
—
2,954
—
(970)
—
—
14,793
—
—
—
—
(5,375)
—
—
10,895 $ 294,270 $
(13,611) $
—
—
—
—
758
671
845
(11,337) $
—
—
—
—
—
(697)
435
(11,599) $
250,704
4,924
(3,010)
39,632
(5,132)
758
671
845
289,392
3,078
(1,002)
—
14,793
(5,375)
(697)
435
300,624
See notes to the Consolidated Financial Statements.
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” or the "Company").
NACCO, through a portfolio of mining and natural resources businesses, operates under three business segments: Coal Mining,
North American Mining ("NAMining") and Minerals Management. The Coal Mining segment operates surface coal mines
under long-term contracts with power generation companies and an activated carbon producer pursuant to a service-based
business model. The NAMining segment provides value-added contract mining and other services for producers of aggregates,
lithium and other minerals. The Minerals Management segment acquires and promotes the development of oil, gas and coal
mineral interests, generating income primarily from royalty-based lease payments from third parties. In addition, the Company
has a business providing stream and wetland mitigation solutions.
The Company also has unallocated 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
During 2020, the Company's operating coal mines were: Bisti Fuels Company, LLC (“Bisti”), Caddo Creek Resources
Company, LLC (“Caddo Creek”), Camino Real Fuels, LLC (“Camino Real”), 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
Company operates these mines as the North American Coal Corporation® ("NACoal").
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. On
November 5, 2020, AEP announced it intends to retire the Pirkey Plant in 2023 in order to comply with the U.S. Environmental
Protection Agency’s Coal Combustion Residuals rule. The Sabine Mine delivered 1.9 million and 2.6 million tons to the Pirkey
Plant in 2020 and 2019, respectively. During 2020, SWEPCO reduced its expected future annual delivery requirements to be
between 1.4 million and 1.7 million tons. The Sabine Mine contributed $3.9 million and $4.6 million to Earnings from
Unconsolidated Operations during 2020 and 2019, respectively.
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 that manufactures synthetic
natural gas and produces fertilizers, solvents, phenol, carbon dioxide, and other chemical products for sale. On November 5,
2020, Basin Electric informed its employees and 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 beginning in 2026. 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. As a result, coal deliveries to the Synfuels Plant are expected to continue until at
least 2026.
On September 30, 2020, Caddo Creek's customer, a division of Cabot Corporation, entered into a long-term supply agreement
with a subsidiary of Advanced Emissions Solutions (“AES”) as well as an agreement for the sale of the Marshall Mine,
operated by Caddo Creek, to a subsidiary of AES. AES announced its intent to close the Marshall Mine. Caddo Creek entered
into a contract with a subsidiary of AES to perform the required mine reclamation. The Marshall Mine delivered 0.1 million and
0.2 million tons during 2020 and 2019, respectively.
The contract mining agreement between Camino Real and its customer, Dos Republicas Coal Partnership (“DRCP”), terminated
effective July 1, 2020 as a result of the unexpected termination by Comisión Federal de Electricidad (“CFE”) of its coal supply
contract with an affiliate of DRCP. The termination of the contract between CFE and DRCP eliminated DRCP’s need for coal
from Camino Real's Eagle Pass Mine, and resulted in mine closure. Mine reclamation is the responsibility of DRCP. Camino
Real has no legal obligation to perform mine reclamation. The Eagle Pass Mine delivered 0.3 million and 1.6 million tons
during 2020 and 2019, respectively.
F-11
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
On May 7, 2020, Great River Energy ("GRE"), Falkirk's customer, announced its intent to retire the Coal Creek Station power
plant in the second half of 2022 and modify the Spiritwood Station power plant to be fueled by natural gas. As noted in the
announcement, GRE is willing to consider opportunities to sell Coal Creek Station. Falkirk Mine is the sole supplier of lignite
coal to Coal Creek Station pursuant to a long-term contract under which Falkirk also supplies approximately 0.3 million tons of
lignite coal per year to Spiritwood Station. Falkirk delivered a total of 7.2 million and 7.4 million tons of lignite coal and
contributed $16.1 million and $15.9 million to Earnings from Unconsolidated Operations during 2020 and 2019, respectively.
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 steady 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.
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 VIE's 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.
Camino Real and Caddo Creek previously met the definition of a VIE of which the Company was not the primary beneficiary
and therefore NACCO did not consolidate the results of operations within its financial statements. As a result of the events
described above, Camino Real and Caddo Creek are no longer VIEs. Camino Real’s and Caddo Creek's financial positions were
consolidated within NACCO’s financial statements during the second quarter of 2020 and the fourth quarter of 2020,
respectively. During 2020, the consolidation of these entities did not materially change the Company’s Consolidated Statements
of Operations and Consolidated Balance Sheet.
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.
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 operates primarily at limestone quarries
in Florida, but is focused on expanding outside of Florida and into mining materials other than limestone. In addition,
NAMining 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 for further
discussion.
F-12
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
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 2020, the Minerals Management segment acquired mineral interests in the Permian Basin 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.
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), Mississippi (coal), Pennsylvania (coal, coalbed methane and
Marcellus shale natural gas), Alabama (coal and coalbed methane and natural gas) and North Dakota (coal). The majority of the
Company’s legacy reserves were acquired as part of its historical coal mining operations. Specialized employees in the
Minerals Management segment also provide surface and mineral acquisition and lease maintenance services related to
Company operations.
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 or 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
oil and natural gas operations. 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.
During the year ended December 31, 2020, the Company closed on multiple acquisitions of mineral and royalty interests for
total consideration of $14.2 million, of which $12.0 million closed in December 2020, $2.0 million closed in November 2020
and $0.2 million closed in August 2020. These acquisitions are all located in the Permian Basin in Texas. The Company did not
acquire any mineral interests in 2019.
Acquisition costs of proven royalty interests are amortized using the units of production method over the life of the property,
which is estimated using proven 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 did
not recognize any amortization expense related to the Company’s royalty interests in oil and natural gas properties for the year
ended December 31, 2020.
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. Proven 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
F-13
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
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.
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 $135 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
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, 2020 and December 31, 2019, 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 79,380 and 85,567 shares related to the
years ended December 31, 2020 and 2019, respectively. After the issuance of these shares, there were 335,053 shares of Class
A common stock available for issuance under these plans. Compensation expense related to these share awards was $2.0
million ($1.6 million net of tax) and $4.1 million ($3.3 million net of tax) for the years ended December 31, 2020 and 2019,
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, 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. For the year ended December 31, 2019,
$95,000 ($150,000 for the Chairman) of the non-employee director's annual retainer of $155,000 ($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 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
F-14
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
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, or (iv) the date the director has both retired from the Board of
Directors and has reached age 70. Pursuant to this plan, the Company issued 42,744 and 22,258 shares related to the years
ended December 31, 2020 and 2019, 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 745 in 2020 and 432 in 2019. After the issuance of these shares, there were 33,821
shares of Class A common stock available for issuance under this plan. Compensation expense related to these awards was
$1.0 million ($0.8 million net of tax) and $1.1 million ($0.9 million net of tax) for the years ended December 31, 2020 and
2019, 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.
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.
On September 30, 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 entities, the management service to oversee the operation of the equipment and delivery of limestone 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
F-15
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
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 and
the general and administrative fee (as applicable). Fluctuations in revenue from period to period result from changes in
customer demand and variances in reimbursable costs primarily due to increases and decreases in activity levels on individual
contracts.
The Company enters into royalty 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 royalty 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-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 coal volumes or MMBtu delivered or limestone tons, however, the terms of these
variable payments relate specifically to our 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. Certain contracts
include reimbursement of actual costs incurred.
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.
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 the timing of 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 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 "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. For the years ended December 31, 2020 and 2019, royalty income recognized in the
reporting periods related to performance obligations satisfied in prior reporting periods was immaterial.
F-16
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
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.
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
2020
2019
72,088 $
42,392
14,721
2,133
(2,902)
128,432 $
68,701
42,823
30,119
790
(1,443)
140,990
68,073 $
60,359
128,432 $
66,102
74,888
140,990
$
$
$
$
The opening and closing balances of the Company’s current and long-term contract liabilities and receivables are as follows:
Trade accounts
receivable, net
Long-term asset
Contract liability
(current)
Contract liability
(long-term)
Balance at January 1, 2020
Balance at December 31, 2020
Increase (decrease)
$
$
15,444
18,894
3,450
$
$
1,977
4,984
3,007
$
$
$
944
941
(3) $
2,153
3,626
1,473
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 both of the years ended December 31, 2020 and December 31, 2019 that was included in
the opening contract liability was $0.9 million. 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 $0.9 million in 2021, $3.1 million in 2022, $0.3 million in 2023, and $0.1 million in 2024 related to the
contract liability remaining at December 31, 2020. 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-17
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
2020
2019
$
$
17,695 $
29,856
47,551 $
15,700
24,765
40,465
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
2020
2019
$
50,887 $
54,647
14,181
231,190
296,258
123,841
$
172,417 $
—
190,868
245,515
107,454
138,061
Total depreciation, depletion and amortization expense on property, plant and equipment was $15.5 million and $13.6 million
during 2020 and 2019, 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, 2020
Coal supply agreement
Balance at December 31, 2019
Coal supply agreement
Gross Carrying
Amount
Accumulated
Amortization
Net
Balance
$
$
84,200 $
(48,870) $
35,330
84,200 $
(46,298) $
37,902
Amortization expense for intangible assets was $2.6 million in both 2020 and 2019.
Expected annual amortization expense of the coal supply agreement for the next five years is as follows: $3.1 million in 2021
and 2022, $3.2 million in 2023, $3.1 million in 2024 and $3.2 million in 2025, respectively.
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
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.
F-18
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
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, 2019
Liabilities incurred during the period
Liabilities settled during the period
Accretion expense
Revision of estimated cash flows
Balance at December 31, 2019
Liabilities incurred during the period
Liabilities settled during the period
Accretion expense
Revision of estimated cash flows
Balance at December 31, 2020
Coal Mining
NAMining
Unallocated
Items
NACCO
Consolidated
$
$
$
20,396 $
—
(8,265)
1,260
5,624
19,015 $
9,809
(5,977)
1,793
400
25,040 $
485 $
91
—
28
—
604 $
—
—
—
(604)
— $
16,822 $
—
(752)
1,323
(153)
17,240 $
—
(732)
1,022
(838)
16,692 $
37,703
91
(9,017)
2,611
5,471
36,859
9,809
(6,709)
2,815
(1,042)
41,732
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 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 liabilities are associated with amounts due to the third-party acquirer upon transfer or replacement of the surety
bonds and the fair value of the obligation to stand ready to perform in the event there is a claim under the surety bonds. As of
December 31, 2020, the Company has $5.8 million of surety bonds outstanding related to the mines associated with the
transferred mine permits. The third party that acquired the mine permits is required as part of the transaction to transfer or
replace the outstanding surety bonds as soon as it is able. If there is a claim under these surety bonds prior to the transfer or
replacement of such bonds, the Company would be responsible to the surety company for any amounts it pays with respect to
such claim, up to the amount of the outstanding surety bonds.
F-19
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
During 2019, the Company transferred the mine permits for certain Centennial mines to an unrelated third party. As a result of
these transfers, the Company was relieved of the associated mine reclamation obligations and recorded a $5.4 million reduction
to Centennial's asset retirement obligation, included in "Liabilities settled during the current period" in the table above. As part
of these transactions, the Company transferred a $3.4 million escrow account and paid $2.4 million of cash, resulting in a net
loss on the transactions of $0.4 million recognized within cost of sales in the Consolidated Statement of Operations and
reflected on the line “Revision of estimated cash flows” in the table above. The reduction to the asset retirement obligation
related to these transfers was offset by a $2.0 million increase to the asset retirement obligation related to updated costs
estimates for the remaining Centennial asset retirement obligations recognized within cost of sales in the Consolidated
Statement of Operations and reflected on the line “Revision of estimated cash flows” in the table above.
Due to updated cost estimates and changes in timing of the asset retirement obligation for MLMC, the Company recognized
a $3.1 million increase to the asset retirement obligation in 2019 within cost of sales in the Consolidated Statement of
Operations and reflected on the line “Revision of estimated cash flows” in the table above.
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.
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 $11.1 million and $10.1 million at December 31, 2020 and December 31, 2019,
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
2020
2019
$
$
$
$
$
$
30,000
16,465
46,465
22,112
24,353
46,465
146,951
116,951
$
$
$
$
$
$
16,000
8,943
24,943
7,795
17,148
24,943
148,644
132,644
Weighted average stated interest rate on total borrowings
2.3 %
5.1 %
F-20
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
Annual maturities of total debt, excluding leases, are as follows:
2021
2022
2023
2024
2025
Thereafter
20,924
10,956
990
1,025
1,061
10,041
44,997
$
Interest paid on total debt was $1.4 million and $0.9 million during 2020 and 2019, respectively.
NACoal has an unsecured revolving line of credit of up to $150.0 million (the “NACoal Facility”) that expires in August 2022.
Borrowings outstanding under the NACoal Facility were $30.0 million at December 31, 2020. At December 31, 2020, the
excess availability under the NACoal Facility was $117.0 million, which reflects a reduction for outstanding letters of credit of
$3.0 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, 2020, for base rate and LIBOR loans
were 0.75% and 1.75%, respectively. The NACoal Facility has a commitment fee which is based upon achieving various levels
of debt to EBITDA ratios. The commitment fee was 0.30% on the unused commitment at December 31, 2020. The weighted
average interest rate applicable to the NACoal Facility at December 31, 2020 was 1.88% including the floating rate margin.
The NACoal Facility contains restrictive covenants, which require, among other things, NACoal to maintain a maximum debt
to EBITDA ratio of 3.00 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 2.00 to 1.00, or if greater than 2.00 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, 2020, NACoal was in compliance with all financial covenants in the NACoal Facility.
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, 2020 and 2019, the balance of the note was $4.4 million and $2.0 million and the interest rate was 0.14% and
1.68%, respectively.
NACoal has two notes payable that are secured by four specified units of equipment and bears interest at a weighted average
rate of 4.20%. One note has a ten year term and includes a principal payment of $4.4 million at the end of the term on
December 15, 2026. The other has a seven year term and expires on April 1, 2027. At December 31, 2020 and 2019, the
outstanding balances of the notes were $10.6 million and $6.3 million, respectively.
F-21
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
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, 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
$
$
—
—
$
$
—
—
Description
December 31, 2019
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
$
$
10,120
10,120
$
$
10,120
10,120
$
$
—
—
$
$
—
—
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 $1.2 million and $1.5 million in the years ended December 31, 2020 and 2019,
respectively. See Note 7 for further discussion of Bellaire's Mine Water Treatment Trust.
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 $0.1
million during the year ended December 31, 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, 2020.
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
F-22
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
the book value of revolving credit agreements and long-term debt, excluding finance leases, was $45.2 million and $45.0
million, respectively, at December 31, 2020 and $24.3 million and $24.3 million, respectively, at December 31, 2019.
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
NACCO adopted ASU 2016-02, Leases (Topic 842), on January 1, 2019. The most significant effect to the Consolidated
Balance Sheet relates to the recognition of new 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.
Leased assets and liabilities include the following:
Description
Assets
Operating
Finance
Liabilities
Current
Operating
Finance
Noncurrent
Operating
Finance
Location
DECEMBER 31
2020
DECEMBER 31
2019
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
$
$
$
10,324 $
1,478
11,398
544
1,457 $
1,188
11,196 $
280
1,318
558
12,448
85
(a) Finance leased assets are recorded net of accumulated amortization of $0.2 million and $1.9 million as of December 31, 2020
and December 31, 2019, respectively.
The components of lease expense for the years ended December 31 are as follows:
Description
Location
2020
2019
Lease expense
Operating lease cost
Finance lease cost:
Selling, general and administrative expenses $
2,103 $
2,251
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
$
164
19
588
260
3,134 $
570
18
555
298
3,692
F-23
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
Future minimum finance and operating lease payments were as follows at December 31, 2020:
2021
2022
2023
2024
2025
Subsequent to 2025
Total minimum lease payments
Amounts representing interest
Present value of net minimum lease payments
Finance
Leases
Operating
Leases
Total
$
$
1,229 $
124
102
63
7
—
1,525
57
3,489
2,260 $
2,305
2,181
1,807
1,705
1,724
1,661
1,476
1,469
7,952
7,952
17,228 $ 18,753
4,575
1,468 $ 12,653
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
2020
2019
8.92
1.38
7.00 %
4.11 %
9.63
0.75
6.99 %
5.95 %
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
$
2020
2019
2,223 $
19
623
2,299
18
534
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.
F-24
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
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, 2020
was 25,000,000 shares and 6,756,176 shares, respectively. Treasury shares of Class A common stock totaling 2,726,017 and
2,817,714 at December 31, 2020 and 2019, respectively, have been deducted from shares outstanding.
Stock Repurchase Programs: On November 6, 2019, the Company's Board of Directors approved a stock purchase program
("2019 Stock Repurchase Program") providing for the purchase of up to $25 million of the Company’s outstanding Class A
common stock through December 31, 2021. NACCO’s previous repurchase program ("2018 Stock Repurchase Program")
would have expired on December 31, 2019 but was terminated and replaced by the 2019 Stock Repurchase Program. As a result
of the uncertainty surrounding the COVID-19 pandemic, the Company suspended repurchasing shares under the 2019 Stock
Repurchase Program in March 2020. Prior to the decision to cease share repurchases, 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 Company repurchased 28,094 and 44,476 shares of Class A common stock under the 2019 Stock Repurchase
Program and 2018 Stock Repurchase Program, respectively, for an aggregate purchase price of $3.0 million during 2019.
The timing and amount of any repurchases under the 2019 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 2019 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 2019 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
2020
2019
7,026
31
7,057
$
$
2.11 $
2.10 $
6,974
33
7,007
5.68
5.66
F-25
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 provision:
Federal
State
Total deferred
2020
2019
13,990 $
268
14,258 $
40,742
2,657
43,399
(7,859) $
(408)
215
(8,052)
7,847
(330)
7,517
(535) $
(6,473)
939
603
(4,931)
8,125
573
8,698
3,767
$
$
$
$
The Company made income tax payments of $0.4 million and $1.0 million during 2020 and 2019, respectively. During the
same periods, income tax refunds totaled $4.2 million and $2.6 million, respectively.
F-26
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
2020
2019
$ 14,258
$ 43,399
$
$
2,994
(626)
426
(3,744)
(367)
6,286
(4,741)
(763)
(535)
$
$
9,114
1,129
736
(4,451)
(255)
(2,377)
—
(129)
3,767
(3.8) %
8.7 %
The Company recorded an 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%), compared to income tax expense of $3.8 million on income before income tax of $43.4 million,
or 8.7%, for the year ended December 31, 2019. 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 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. Discrete tax items in the
year ended December 31, 2019 were a benefit of $2.5 million primarily resulting from changes in prior year estimates and the
effective settlement of certain discrete tax items from on-going examinations.
The Company’s effective income tax rate, excluding the CARES Act and discrete items, was (22.0%) and 14.5% for the years
ended December 31, 2020 and 2019, respectively. The effective income tax rate differs from the U.S. federal statutory rate
primarily due to the benefit from percentage depletion. The benefit of percentage depletion is not directly related to the amount
of pre-tax income recorded in a period. Accordingly, as a result of the $29.1 million reduction in income before income tax in
2020 compared to 2019, the proportional effect of the benefit from percentage depletion on the effective income tax rate in
2020 resulted in a significantly lower effective tax rate in 2020 compared to 2019.
F-27
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. Significant components of the Company’s deferred tax assets and liabilities are 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
2020
2019
$
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
30,875
16,305
1,704
10,020
4,853
4,304
4,701
72,762
12,296
60,466
30,875
28,061
9,949
3,919
72,804
$
(17,550) $
(12,338)
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
Federal research credit
Total
State net operating loss
Federal research credit
Federal foreign tax credit
Alternative minimum tax ("AMT") credit
Total
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
December 31, 2019
Net deferred tax
asset
Valuation
allowance
Carryforwards
expire during:
$
16,531 $
13,668
2020-2039
1,455
463
1,596
—
463
—
2034-2038
2029
(1)
$
20,045 $
14,131
F-28
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
(1) The Tax Cuts and Jobs Act provided that AMT credits can be utilized to offset income taxes owed in tax years 2018 through
2020 with any remaining AMT credit refundable in 2021. The CARES Act revised this to allow AMT credits to be refundable
in 2018 and 2019. The Company has reclassified its AMT credits to the current receivable as of December 31, 2020.
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.
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, 2020 and 2019. The increase in the gross unrecognized tax benefits in 2020 is primarily due to tax positions
related to worthlessness losses for which the timing of deductibility is uncertain. Approximately $6.3 million and $2.3 million
of the gross unrecognized tax benefits as of December 31, 2020 and 2019, 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
2020
2019
$
2,860 $
2,774
(803)
5,628
$
10,459 $
1,280
1,172
—
408
2,860
The Company records interest and penalties on uncertain tax positions as a component of the income tax provision. The
Company recognized net benefit of less than $0.1 million and net expense of less than $0.1 million in interest and penalties
related to uncertain tax positions during 2020 and 2019, respectively. The total amount of interest and penalties accrued was
$0.1 million as of December 31, 2020 and 2019, 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.
During the year ended December 31, 2019, the Company offered lump-sum settlements to certain Combined Plan participants.
These lump sum payments resulted in a pension settlement charge of $0.9 million.
F-29
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
2020
2019
2.02% - 2.36% 2.98% - 3.20%
2.98% - 3.20% 4.10% - 4.20%
Expected long-term rate of return on assets for net periodic benefit cost
7.00 %
7.50 %
Set forth below is a detail of the net periodic pension (income) expense 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
Settlements
2020
2019
$
1,285 $
(2,435)
1,710
(2,778)
597
58
—
422
58
873
285
Net periodic pension (income) expense
$
(495) $
Set forth below is detail of other changes in plan assets and benefit obligations recognized in other comprehensive loss
(income) for the years ended December 31:
Current year actuarial loss (gain)
Amortization of actuarial loss
Amortization of prior service cost
Settlements
2020
2019
$
667 $
(1,030)
(597)
(58)
—
(422)
(58)
(873)
Total recognized in other comprehensive loss (income)
$
12 $
(2,383)
F-30
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:
Change in benefit obligation
Projected benefit obligation at beginning of year
$
41,854 $
2020
2019
Interest cost
Actuarial loss
Benefits paid
Settlements
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
Settlements
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 (income) consist of:
Actuarial loss
Prior service cost
Deferred taxes
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 $
$
$
$
$
$
$
$
$
$
42,026
1,710
3,121
(2,391)
(2,612)
41,854
41,854
34,954
6,930
483
(2,391)
(2,612)
37,364
(4,490)
3,079
(606)
(6,963)
(4,490)
13,951
819
(3,305)
11,465
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-31
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:
2021
2022
2023
2024
2025
2026 - 2030
$
$
2,631
2,600
2,676
2,695
2,666
12,866
26,134
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
2020
Actual
Allocation
2019
Actual
Allocation
Target Allocation
Range
45.4 %
20.3 %
33.9 %
0.4 %
45.1 % 36.0% - 54.0%
20.0 % 16.0% - 24.0%
34.4 % 30.0% - 40.0%
0.5 % 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
2020
2019
$
18,640 $
16,862
8,335
13,948
176
7,482
12,854
166
$
41,099 $
37,364
F-32
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
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
were amended effective January 1, 2019 to eliminate the open network structure. The move to network provided benefits will
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.
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
2020
1.37 %
1.37% - 2.65%
6.25 %
5.0 %
2027
2019
2.65 %
3.80 %
6.50 %
5.0 %
2025
Set forth below is a detail of the net periodic benefit (income) expense for the postretirement health care plans for the years
ended December 31:
Service cost
Interest cost
Amortization of actuarial (gain) loss
Amortization of prior service credit
Amortization of curtailment
Net periodic benefit (income) expense
2020
2019
$
21 $
52
(1)
(59)
(31)
$
(18) $
24
77
8
(80)
—
29
Set forth below is a detail of other changes in plan assets and benefit obligations recognized in other comprehensive income for
the years ended December 31:
Current year actuarial loss
Amortization of actuarial gain (loss)
Amortization of prior service credit
Amortization of curtailment
Transfers
2020
2019
$
194 $
1
59
31
46
46
(8)
80
—
—
Total recognized in other comprehensive income
$
331 $
118
F-33
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 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 (income) consist of:
Actuarial loss
Prior service credit
Deferred taxes
Future postretirement health care benefit payments expected to be paid are:
2021
2022
2023
2024
2025
2026 - 2030
2020
2019
$
2,049 $
2,113
$
$
$
$
$
$
21
52
49
145
(262)
2,054 $
(2,054) $
(238) $
(1,816)
(2,054) $
466 $
(167)
(167)
132 $
$
24
77
—
46
(211)
2,049
(2,049)
(204)
(1,845)
(2,049)
227
(259)
(96)
(128)
239
226
211
196
171
688
1,731
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 $2.8 million and $2.7 million in
2020 and 2019, 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 of North America® (“MRNA”) and Bellaire. MRNA
F-34
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
generates and sells stream 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.
As of January 1, 2020, the Company retrospectively changed its computation of segment operating profit to reclassify certain
expenses, primarily related to executive and board compensation. These expenses are now included in unallocated items. The
change in segment reporting reflected a decision to evaluate the financial performance of the Company’s segments excluding
executive and board compensation. All prior period segment information has been reclassified to conform to the new
presentation. This segment reporting change has no impact on consolidated operating results.
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.
Included within other income on the line Income from other unconsolidated affiliates within the Consolidated Statements of
Operations is the financial results of NoDak Energy Services, LLC ("NoDak"). NoDak operated and maintained a coal drying
system at a customer’s power plant. The NoDak contract expired in the first quarter of 2020.
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.
In 2020, two customers individually accounted for more than 10% of consolidated revenue. In 2019, two customers and an oil
and gas lessee 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
Minerals Management lessee
less than 10%
Percentage of Consolidated
Revenue
2020
2019
55 %
19 %
48 %
21 %
12 %
In addition, for the year ended December 31, 2020, the Coal Mining segment derived approximately 60% of the Earnings of
Unconsolidated Operations from two customers, Basin Electric and GRE. GRE announced its intent to close Coal Creek station
in 2022.
F-35
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
2020
2019
$
72,088 $
42,392
14,721
2,133
68,701
42,823
30,119
790
(2,902)
(1,443)
$
128,432 $
140,990
$
25,436 $
34,120
1,872
3,493
(564)
25,721
(17,256)
(20,713)
(97)
256
$
13,448 $
38,820
$
14,825 $
15,092
13,862
15,474
207
8,824
517
231
$
44,368 $
24,664
$
14,213 $
12,409
2,470
1,308
123
2,223
1,362
246
$
18,114 $
16,240
Asset information by segment is not discretely maintained for internal reporting or used in evaluating performance.
F-36
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
Current intercompany accounts receivable, net
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
Current portion of deferred compensation
Note payable to Bellaire
Other non-current liabilities
Stockholders’ equity
$
$
$
2020
2019
85,365 $
495
—
20,648
211,468
110
5,890
120,016
515
1,255
10,448
189,338
167
4,570
323,976 $
326,309
3,242 $
2,337
—
16,750
1,023
300,624
5,257
—
13,465
16,950
1,245
289,392
326,309
Total Liabilities and Stockholders’ Equity
$
323,976 $
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, 2020 totaled approximately $1.7 million. The amount of unrestricted
cash available to NACCO included in “Investment in subsidiaries” was $0.7 million at December 31, 2020. 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 $29.0 million and $24.6 million at
December 31, 2020 and 2019, respectively. The Company's risk of loss relating to these entities is limited to its invested capital,
which was $6.5 million and $5.0 million at December 31, 2020 and 2019, 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
F-37
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
(Tabular Amounts in Thousands, Except Per Share and Percentage Data)
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.
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
2020
2019
$
$
$
$
$
$
$
$
768,660 $
734,515
69,021 $
60,398 $
50,933 $
72,433
65,183
54,067
186,934 $
183,848
959,032 $
837,477
143,843 $
141,132
995,658 $
875,216
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 $49.7 million and $53.5 million from the Unconsolidated Subsidiaries in 2020 and 2019,
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 $1.0 million
for both of the years ended December 31, 2020 and 2019.
Alfred M. Rankin, Jr. retired as the President and Chief Executive Officer of NACCO effective during 2017. Mr. Rankin
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, 2020 and 2019.
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. As of
December 31, 2020, $1.6 million was unpaid and recorded in Accrued payroll in the Consolidated Balance Sheet.
F-38
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
Current intercompany accounts receivable, net
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
Current portion of deferred compensation
Note payable to Bellaire
Other non-current liabilities
Stockholders’ equity
December 31
2020
2019
(In thousands)
$
85,365 $
120,016
$
$
495
—
20,648
211,468
110
5,890
515
1,255
10,448
189,338
167
4,570
323,976 $
326,309
3,242 $
2,337
—
16,750
1,023
300,624
5,257
—
13,465
16,950
1,245
289,392
326,309
Total Liabilities and Stockholders’ Equity
$
323,976 $
See Notes to Parent Company Condensed Financial Statements.
F-39
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 provision (benefit)
Net loss before equity in earnings of subsidiaries
Equity in earnings of subsidiaries
Net income
Current period pension and postretirement plan adjustment, net of $213 tax benefit and $226
tax expense in 2020 and 2019, respectively
Pension settlement, net of $202 tax benefit in 2019
Reclassification of pension and postretirement adjustments into earnings, net of $129 and $90
tax benefit in 2020 and 2019, respectively
Total other comprehensive income
Comprehensive Income
See Notes to Parent Company Condensed Financial Statements.
Year Ended December 31
2020
2019
(In thousands)
$
1,178 $
(1,003)
175
5,658
(5,833)
2,419
(8,252)
23,045
14,793
(697)
—
435
(262)
1,190
(1,796)
(606)
6,403
(5,797)
(3,819)
(1,978)
41,610
39,632
758
671
845
2,274
$
14,531 $
41,906
F-40
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 (used for) provided by operating activities
Investing Activities
Expenditures for property, plant and equipment
Net cash used for investing activities
Financing Activities
Dividends received from subsidiaries
Notes payable to Bellaire
Purchase of treasury shares
Cash dividends paid
Other
Year Ended December 31
2020
2019
(In thousands)
$
14,793 $
23,045
39,632
41,610
(8,252)
(1,978)
(22,822)
(31,074)
3,671
1,693
—
—
3,000
(200)
(1,002)
(5,375)
—
—
—
42,000
(350)
(3,010)
(5,132)
(4)
Net cash (used for) provided by financing activities
(3,577)
33,504
Cash and cash equivalents
Increase (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.
(34,651)
120,016
35,197
84,819
$
85,365 $
120,016
F-41
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, 2020 AND 2019
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
NACCO Industries, Inc.® (“NACCO” or the “parent company”) is the public holding company for The North American Coal
Corporation® ("NACoal"). 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 $0.7 million at December 31,
2020 and was in addition to the $85.4 million of cash included in the Parent Company Condensed Balance Sheet at
December 31, 2020.
F-42
SCHEDULE II—VALUATION AND QUALIFYING ACCOUNTS
NACCO INDUSTRIES, INC. AND SUBSIDIARIES
YEAR ENDED DECEMBER 31, 2020 AND 2019
Description
2020
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
$ 12,296 $
(747) $
—
—
$ 11,549
2019
Reserves deducted from asset accounts:
Deferred tax valuation allowances
$ 14,219 $ (1,923) $
— $ —
$ 12,296
(A)
Balances which are not required to be presented and those which are immaterial have been omitted.
F-43
SUBSIDIARIES OF NACCO INDUSTRIES, INC.
Exhibit 21
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.
Name
America Lignite Energy LLC
Bellaire Corporation
Bisti Fuels Company, LLC
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 - Corkscrew, LLC
NAM - CSA, LLC
NAM - Newberry, LLC
NAM - MCA, LLC
NAM - PBA, LLC
NAM - Pasco, LLC
NAM - Perry, LLC
NAM - QueenField, LLC
NAM - SACC, LLC
NAM - SDI, LLC
NAM - WFA, LLC
NAM - WRQ, LLC
NoDak Energy Investments Corporation
NoDak Energy Services, LLC
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
Shondenah Energy, LLC
TRU Global Energy Services, LLC
TRU Energy Services, LLC
Reed Minerals, Inc.
Yockanookany Mitigation Resources, LLC
Incorporation
Delaware (50%)
Ohio
Nevada
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
Delaware
Delaware
India
Nevada
Delaware
Nevada
Mississippi
Nevada
Nevada
Nevada
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 3, 2021
/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 3, 2021
/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, 2020, 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 3, 2021
Date: March 3, 2021
/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,
2018. 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, 2020, 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, 2020.
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, 2020, and the total number of legal
actions pending before the FMSHRC at December 31, 2020, 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,
2020
Number of Legal
Actions Resolved
before the
FMSHRC for the
year ended at
December 31,
2020
Number of Legal
Actions Pending
before the
FMSHRC at
December 31,
2020
—
—
2
—
—
1
—
3
—
—
—
—
—
—
—
—
—
—
—
—
—
—
1
—
—
—
—
—
1
—
8
—
$
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
246
260
1,687
—
—
1,990
369
3,085
—
—
—
123
—
123
—
125
—
—
—
—
123
—
2,394
—
258
123
—
—
288
—
—
$
11,194
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
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)
Camino Real (Eagle Pass Mine)
Coyote Creek (Coyote Creek Mine)
Bisti Fuels (Navajo Mine)
MLMC (Red Hills Mine)
North American Mining Operations:
Card Sound Quarry
White Rock Quarry - North
Krome Quarry
Alico Quarry
FEC Quarry
SCL Quarry
Central State Aggregates Quarry
Mid Coast Aggregates Quarry
West Florida Aggregates Quarry
St. Catherine Quarry
Center Hill Quarry
Inglis Quarry
Titan Corkscrew Quarry
Palm Beach Aggregates Quarry
Perry Quarry
SDI Aggregates Quarry
Queensfield Mine
County Line Quarry
Newberry Quarry
Titan Pennsuco
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 Newberry Quarry during the year ended December 31, 2020, was originally classified by MSHA as
significant and substantial. The citation has been reduced to non-significant and substantial.
(THIS PAGE INTENTIONALLY LEFT BLANK)
Directors and Officers
NACCO Industries, Inc.
The North American Coal Corporation
Directors:
Officers:
Officers:
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
J.C. Butler, Jr.
President and Chief Executive Officer
J. C. Butler, Jr.
President and Chief Executive Officer
Elizabeth I. Loveman
Vice President and Controller
Carroll L. Dewing
Vice President – Operations
Thomas A. Maxwell
Vice President – Financial Planning and
Analysis and Treasurer
John D. Neumann
Vice President, General Counsel and
Secretary
John D. Neumann
Vice President, General Counsel and
Secretary
Sarah E. Fry
Associate General Counsel and
Assistant Secretary
Miles B. Haberer
Associate General Counsel
Matthew J. Dilluvio
Associate Counsel and Assistant Secretary
J. Patrick Sullivan, Jr.
Vice President and Chief Financial Officer
Eric S. Anderson
President, Mitigation Resources of
North America
Philip N. Berry
President, North American Mining
Brian M. Larson
President, Catapult Mineral Partners
Eric A. Dale
Treasurer and Senior Director,
Financial Planning and Analysis
Andrew B. Hart
Controller
Sarah E. Fry
Associate General Counsel and
Assistant Secretary
Miles B. Haberer
Associate General Counsel,
Assistant Secretary and President,
North American Coal Royalty Company
Matthew J. Dilluvio
Associate Counsel and Assistant Secretary
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)
NACCO Industries®
Corporate Information
Annual Meeting
The Annual Meeting of Stockholders of NACCO
Industries, Inc. will be held on May 19, 2021, at
11:00 a.m. located at: 5875 Landerbrook Drive,
Cleveland, Ohio 44124
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
NACCO Industries
5875 Landerbrook Drive, Suite 220
Cleveland, Ohio 44124
(440) 229-5130
Independent Registered Public
Accounting Firm
Ernst & Young LLP
950 Main Ave., Suite 1800
Cleveland, Ohio 44113
Stock Exchange Listing
The New York Stock Exchange
Symbol: NC
Investor Relations Contact
Investor questions may be addressed to:
Investor Relations
NACCO Industries
5875 Landerbrook Drive, Suite 220
Cleveland, Ohio 44124
(440) 229-5130
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
NACCO Industries Website
Additional information about NACCO Industries may
be found at nacco.com. The Company considers this
website to be one of the primary sources of information
for investors and other interested parties.
North American Coal Website
Additional information about North American
Coal may be found at nacoal.com.
11
®
5875 Landerbrook Drive, Suite 220 • Cleveland, Ohio 44124
An Equal Opportunity Employer
12