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EX-99 - EXHIBIT 99 - NACCO INDUSTRIES INCexhibit99201510-k.htm
EX-21 - EXHIBIT 21 - NACCO INDUSTRIES INCexhibit21201510-k.htm
EX-4.4 - EXHIBIT 4.4 - NACCO INDUSTRIES INCexhibit44.htm
EX-31.2 - EXHIBIT 31.2 - NACCO INDUSTRIES INCexhibit312201510-k.htm
EX-10.72 - EXHIBIT 10.72 - NACCO INDUSTRIES INCexhibit1072.htm
EX-24.6 - EXHIBIT 24.6 - NACCO INDUSTRIES INCexhibit246201510-k.htm
EX-24.7 - EXHIBIT 24.7 - NACCO INDUSTRIES INCexhibit247201510-k.htm
EX-24.5 - EXHIBIT 24.5 - NACCO INDUSTRIES INCexhibit245201510-k.htm
EX-10.57 - EXHIBIT 10.57 - NACCO INDUSTRIES INCexhibit1057.htm
EX-24.3 - EXHIBIT 24.3 - NACCO INDUSTRIES INCexhibit243201510-k.htm
EX-24.2 - EXHIBIT 24.2 - NACCO INDUSTRIES INCexhibit242201510-k.htm
EX-31.1 - EXHIBIT 31.1 - NACCO INDUSTRIES INCexhibit311201510-k.htm
EX-10.77 - EXHIBIT 10.77 - NACCO INDUSTRIES INCexhibit1077.htm
EX-32 - EXHIBIT 32 - NACCO INDUSTRIES INCexhibit32201510-k.htm
EX-23.1 - EXHIBIT 23.1 - NACCO INDUSTRIES INCexhibit231201510-k.htm
EX-24.8 - EXHIBIT 24.8 - NACCO INDUSTRIES INCexhibit248201510-k.htm
EX-24.1 - EXHIBIT 24.1 - NACCO INDUSTRIES INCexhibit241201510-k.htm
EX-95 - EXHIBIT 95 - NACCO INDUSTRIES INCexhibit95201510-k.htm
EX-10.60 - EXHIBIT 10.60 - NACCO INDUSTRIES INCexhibit1060.htm
EX-24.4 - EXHIBIT 24.4 - NACCO INDUSTRIES INCexhibit244201510-k.htm


 
 
 
 
 

UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
WASHINGTON, DC 20549
FORM 10-K
(Mark One)
 
 
þ
 
ANNUAL REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
 
 
For the fiscal year ended December 31, 2015
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)
Registrant's telephone number, including area code: (440) 229-5151

Securities registered pursuant to Section 12(b) of the Act:
Title of each class
 
Name of each exchange on which registered
Class A Common Stock, Par Value $1.00 Per Share
 
New York Stock Exchange

Securities registered pursuant to Section 12(g) of the Act:
Class B Common Stock, Par Value $1.00 Per Share
(Title of class)

Indicate by check mark if the registrant is a well-known seasoned issuer, as defined in Rule 405 of the Securities Act.
     YES ¨    NO þ
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
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 and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted 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 and post such files).
     YES þ     NO £
Indicate by check mark if disclosure of delinquent filers pursuant to Item 405 of Regulation S-K (§ 229.405) is not contained herein, and will not be contained, to the best of registrant's knowledge, in definitive proxy or information statements incorporated by reference in Part III of this Form 10-K or any amendment to this Form 10-K. ¨
Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See definitions of “large accelerated filer,” “accelerated filer,” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.
Large accelerated filer ¨
Accelerated filer þ 
Non-accelerated filer ¨
(Do not check if a smaller reporting company)
Smaller reporting company ¨

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act)
     YES ¨    NO þ
Aggregate market value of Class A Common Stock and Class B Common Stock held by non-affiliates as of June 30, 2015 (the last business day of the registrant's most recently completed second fiscal quarter): $266,826,629
Number of shares of Class A Common Stock outstanding at February 26, 2016: 5,303,607
Number of shares of Class B Common Stock outstanding at February 26, 2016: 1,571,552
DOCUMENTS INCORPORATED BY REFERENCE

Portions of the Company's Proxy Statement for its 2016 annual meeting of stockholders are incorporated herein by reference in Part III of this Form 10-K.

 
 
 
 
 



NACCO INDUSTRIES, INC.
TABLE OF CONTENTS
 
 
 
PAGE
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 

2


PART I
Item 1. BUSINESS
General
NACCO Industries, Inc. (“NACCO” or the “Company”) is a holding company with the following principal businesses: mining, small appliances and specialty retail.
(a)North American Coal. The Company’s wholly owned subsidiary, The North American Coal Corporation and its affiliated companies (collectively, “NACoal”), mine coal primarily for use in power generation and provide selected value-added mining services for other natural resources companies.
(b)Hamilton Beach Brands. The Company’s wholly owned subsidiary, Hamilton Beach Brands, Inc. (“HBB”), is a leading designer, marketer and distributor of small electric household and specialty housewares appliances, as well as commercial products for restaurants, bars and hotels.
(c)Kitchen Collection. The Company’s wholly owned subsidiary, The Kitchen Collection, LLC (“KC”), is a national specialty retailer of kitchenware in outlet and traditional malls throughout the United States. 
Additional information relating to financial and operating data on a segment basis (including NACCO and Other) and by geographic region is set forth under the heading “Management’s Discussion and Analysis of Financial Condition and Results of Operations” contained in Part II of this Form 10-K and in Note 17 to the Consolidated Financial Statements contained in this Form 10-K.
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. As of December 31, 2015, the Company and its subsidiaries had approximately 3,600 employees, including approximately 1,550 employees at the Company’s unconsolidated mines.
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”).
Significant Events

During the fourth quarter of 2015, Bisti Fuels Company, LLC ("Bisti"), a wholly owned subsidiary of NACoal, entered into a 15-year, cost-plus contract mining agreement with Navajo Transitional Energy Company, LLC ("NTEC"). Under the agreement, Bisti will act as NTEC's contract miner at NTEC's Navajo Mine, a surface coal mine located within the Navajo Nation near Fruitland, San Juan County, New Mexico. Production is expected to be between 5.0 million to 6.0 million tons of coal per year. Pursuant to a separate agreement, NTEC will sell and deliver that coal to the third-party owners of the nearby Four Corners Generating Station. Similar to most of NACoal's other agreements, the agreement between Bisti and NTEC is a cost-plus arrangement, under which NTEC will reimburse Bisti for all operating costs of the mine and pay NACoal an agreed fee per Btu of heating value delivered. The agreement consists of a transition period and a production period. During the transition period, which commenced on January 1, 2016, Bisti will transition into the contract miner role. The production period is scheduled to commence when NTEC completes a pending commercial transaction with the existing contract miner, which is expected to occur during the second half of 2016. 

On July 31, 2015, NACoal's management and Board of Directors approved cessation of coal production at its Centennial Natural Resources, LLC ("Centennial") mines in Alabama. NACoal ceased coal production at Centennial during the fourth quarter of 2015. The decision was made as a result of worsening conditions in the Alabama and global coal markets and the adverse effect regulatory changes have had on Centennial’s business.

During the fourth quarter of 2014, NACoal determined that indicators of impairment existed at Centennial and, as a result, reviewed Centennial's long-lived assets for impairment. NACoal recorded a non-cash, asset impairment charge of $105.1 million in 2014 for Centennial's long-lived asset group.

During 2014, NACoal recognized a gain of $3.5 million from the sale of assets to Mississippi Power Company and an unrelated gain of $2.2 million from the sale of land.

In 2013, NACoal concluded during its annual assessment for impairment of goodwill that the goodwill within the Centennial reporting unit was fully impaired and, as a result, recorded a $4.0 million non-cash, goodwill impairment charge during the fourth quarter.
On December 16, 2014, HBB acquired Weston Products, LLC, which HBB refers to as Weston Brands, in exchange for cash consideration of $25.4 million, of which $25.0 million was paid at closing in 2014. As a result of the 2014 Weston Brands

1


acquisition, HBB now markets a range of game and garden food processing equipment including, but not limited to, meat grinders, bag sealers, dehydrators and meat slicers under the Weston® brand as well as several private label brands. The results of Weston Brands operations have been included in the Company's Consolidated Financial Statements since December 16, 2014.

During 2015, HBB entered the "only-the-best" product market and began selling Wolf Gourmet® and Jamba® branded products under licensing agreements with Sub-Zero Group, Inc. and Jamba Juice Company, respectively.

During 2013, 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, including those for certain unconsolidated mines' employees and cost of living adjustments for other employees, effective as of the close of business on December 31, 2013. As a result of this amendment, the Company remeasured the Combined Plan and recorded a $1.7 million pre-tax curtailment gain during the third quarter of 2013.

In November 2013, NACCO announced a $60 million stock repurchase program. During 2015, the Company completed the stock repurchase program with total repurchases of approximately 1,122,900 shares of Class A common stock. Under a previous stock repurchase program, which was in place from November 2011 to November 2013, the Company repurchased an additional 624,000 shares of Class A common stock for an aggregate purchase price of $35.6 million.


A. North American Coal
General
NACoal mines coal primarily for use in power generation and provides selected value-added mining services for other natural resources companies. Coal is surface mined from NACoal's developed mines in North Dakota, Texas, Mississippi and Louisiana. When Bisti commences mining coal for NTEC, it will be surface mined on the Navajo Nation in New Mexico. Total coal reserves approximate 2.0 billion tons (including the unconsolidated mining operations) with approximately 1.1 billion tons committed to customers pursuant to long-term contracts. NACoal has two consolidated mining operations: Mississippi Lignite Mining Company (“MLMC”) and Centennial. Centennial ceased coal production in the fourth quarter of 2015. NACoal also provides dragline mining services for independently owned limerock quarries in Florida. NACoal has the following wholly owned unconsolidated subsidiaries: The Coteau Properties Company (“Coteau”), The Falkirk Mining Company (“Falkirk”), The Sabine Mining Company (“Sabine”), Demery Resources Company, LLC (“Demery”), Caddo Creek Resources Company, LLC (“Caddo Creek”), Coyote Creek Mining Company, LLC (“Coyote Creek”), Camino Real Fuels, LLC (“Camino Real”), Liberty Fuels Company, LLC (“Liberty”), Bisti and NoDak Energy Services, LLC ("NoDak").

The unconsolidated subsidiaries, with the exception of NoDak, were formed to develop, construct and/or operate surface coal mines under long-term contracts and are capitalized primarily with debt financing provided by or supported by their respective customers, and without recourse to NACCO and NACoal. The contracts with the customers of the unconsolidated subsidiaries provide for reimbursement to the company at a price based on actual costs plus an agreed pre-tax profit per ton of coal sold or actual costs plus a management fee. The fees earned at each mine adjust over time in line with various indices which reflect general inflation rates. 

Coteau, Falkirk, Sabine, Liberty and Coyote supply or will supply lignite coal for power generation. Demery and Caddo Creek supply lignite coal for the production of activated carbon. Camino Real supplies sub-bituminous coal for power generation. Bisti will supply sub-bituminous coal for power generation. NoDak operates and maintains a coal processing facility.

Coteau, Falkirk and Sabine were developed between 1974 and 1984. Demery commenced delivering coal in 2012 and anticipates achieving full production levels in 2017. Caddo Creek commenced delivering coal in late 2014. Camino Real commenced delivering coal in October 2015, and expects to mine approximately 2.5 million to 2.7 million tons of coal annually when at full production.

Liberty commenced production in 2013 but did not deliver any coal for power generation in 2015. Production levels at Liberty are expected to increase gradually beginning in 2016 and build to full production of approximately 4.6 million tons of coal annually beginning in 2023, although the timing of future deliveries will be affected by when the Kemper County Energy Facility is commissioned.

Coyote Creek is developing a mine in Mercer County, North Dakota, from which it expects to deliver approximately 2.5 million tons of coal annually beginning in mid-2016.

2



Bisti anticipates that it will replace an existing contract miner at an existing mine during the second half of 2016, after which it will make annual coal deliveries of between 5.0 million to 6.0 million tons.

At December 31, 2015, NACoal's operating mines consisted both of mines where the reserves were acquired (whether in fee or through leases) and developed by NACoal, as well as mines where reserves are owned or leased by the customers of the mines and developed by NACoal. It is currently contemplated that the reported reserves will be mined within the terms of the majority of the leases for each of the mines. In the future, if any of the leases are projected to expire before mining operations can commence, it is currently expected that each such lease would be amended to extend the term or new leases would be negotiated. NACoal expects coal mined pursuant to these leases will be available to meet production requirements.

The majority of NACoal's revenue is generated from its consolidated mining operations and dragline mining services. MLMC's customer, Choctaw Generation Limited Partnership until February 28, 2013 and KMRC RH, LLC subsequent to February 28, 2013, accounted for approximately 57%, 39% and 42% of NACoal's revenues for the years ended December 31, 2015, 2014 and 2013, respectively. Centennial's largest customer, Alabama Coal Cooperative, accounted for approximately 16% of NACoal's revenues for the year ended December 31, 2015 and approximately 27% of NACoal's revenues for both 2014 and 2013. Centennial ceased coal production in 2015.

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 is pursuing contractual remedies.
Sales, Marketing and Operations
The principal coal customers of NACoal are electric utilities, an independent power provider and a synfuels plant. During 2015, Centennial sold coal to coke processing plants, cement plants and coal brokers in Alabama. The distribution of coal sales, including sales from the unconsolidated mines, in the last five years has been as follows:
 
Distribution
 
Synfuels Plant
 
Other
2015
20
%
 
80
%
2014
20
%
 
80
%
2013
19
%
 
81
%
2012
21
%
 
79
%
2011
22
%
 
78
%
The total coal severed by mine (in millions of tons) for the three years ended December 31 and the weighted average prices per ton delivered for the three years ended December 31 are as follows:
 
2015
 
2014
 
2013
Unconsolidated Mines
 
 
 
 
 
Freedom — The Coteau Properties Company
14.3

 
14.4

 
13.8

Falkirk — The Falkirk Mining Company
8.0

 
8.0

 
7.7

South Hallsville No. 1  The Sabine Mining Company
3.6

 
4.4

 
3.9

Other
1.2

 
1.0

 
0.3

Consolidated Mines
 
 
 
 
 
Red Hills — Mississippi Lignite Mining Company
3.0

 
2.9

 
3.3

Centennial Natural Resources
0.4

 
0.9

 
0.9

Total tons severed
30.5

 
31.6

 
29.9

Price per ton delivered
$
23.63

 
$
23.75

 
$
24.32


The contracts under which certain of the unconsolidated mines operate provide that, under certain conditions, including default, the customer(s) involved may elect or be obligated to acquire the assets (subject to the liabilities) or the capital stock of the

3


NACoal mining subsidiary for an amount effectively equal to book value. NACoal does not know of any conditions of default that currently exist.
The location, mine type, reserve data, coal quality characteristics, sales tonnage and contract expiration date for the mines operated by NACoal were as follows:

COAL MINING OPERATIONS ON AN “AS RECEIVED” BASIS
 
 
 
 
2015
 
2014
 
 
 
 
 
 
 
Proven and Probable Reserves (a)(b)
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Committed
Under
Contract
 
Uncommitted
 
Total
 
Tons
Delivered
(Millions)
 
Owned
Reserves
(%)
 
Leased
Reserves
(%)
 
Total
Committed
and
Uncommitted
(Millions of
Tons)
 
Tons
Delivered
(Millions)
 
Contract
Expires
Mine/Reserve
 
Type of Mine
 
(Millions of Tons)
 
 
 
 
 
 
Unconsolidated Mines
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Freedom Mine (c)
 
Surface Lignite
 
480.7

 

 
480.7

 
14.4

 
3
%
 
97
%
 
495.7

 
14.3

 
2022
(d)
Falkirk Mine (c)
 
Surface Lignite
 
390.4

 

 
390.4

 
8.0

 
1
%
 
99
%
 
399.1

 
7.8

 
2045
 
South Hallsville No. 1 Mine (c)
 
Surface Lignite
 
(e)

 
(e)

 
(e)

 
3.7

 
(e)

 
(e)

 
(e)

 
4.5

 
2035
 
Five Forks Mine (c)
 
Surface Lignite
 
(e)

 
(e)

 
(e)

 
0.2

 
(e)

 
(e)

 
(e)

 
0.1

 
2030
 
Marshall Mine (c)
 
Surface Lignite
 
(e)

 
(e)

 
(e)

 
0.2

 
(e)

 
(e)

 
(e)

 
(f)

 
2044
 
Eagle Pass Mine (c)
 
Surface
Sub-bituminous
 
(e)

 
(e)

 
(e)

 
0.5

 
(e)

 
(e)

 
(e)

 
(g)

 
2018
 
Liberty Mine (c)
 
Surface Lignite
 
(e)

 
(e)

 
(e)

 
(h)

 
(e)

 
(e)

 
(e)

 
(h)

 
2055
(i)
Coyote Creek Mine (c)
 
Surface Lignite
 
79.0

 

 
79.0

 
(j)

 
0
%
 
100
%
 
78.9

 
(j)

 
2040
 
Navajo Mine (c)
 
Surface
Sub-bituminous
 
(e)

 
(e)

 
(e)

 
(k)

 
(e)

 
(e)

 
(e)

 
(k)

 
2031
 
Consolidated Mines
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Centennial Natural Resources
 
Surface Bituminous
 

 
60.3

 
60.3

 
0.4

 
28
%
 
72
%
 
64.6

 
0.9

 
(l)
 
Red Hills Mine
 
Surface Lignite
 
116.7

 
115.9

 
232.6

 
3.2

 
33
%
 
67
%
 
236.5

 
2.6

 
2032
 
Total Developed
 
 
 
1,066.8

 
176.2

 
1,243.0

 
30.6

 
 
 
 
 
1,274.8

 
30.2

 
 
 
Undeveloped Mines
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
North Dakota
 
 
 

 
283.2

 
283.2

 

 
0
%
 
100
%
 
287.3

 

 
 
 
Texas
 
 
 

 
225.6

 
225.6

 

 
54
%
 
46
%
 
225.6

 

 
 
 
Eastern (m)
 
 
 

 
28.7

 
28.7

 

 
100
%
 
0
%
 
28.7

 

 
 
 
Mississippi
 
 
 

 
187.8

 
187.8

 

 
0
%
 
100
%
 
187.8

 

 
 
 
Total Undeveloped
 
 
 

 
725.3

 
725.3

 

 
 
 
 
 
729.4

 

 
 
 
Total Developed/Undeveloped
 
 
 
1,066.8

 
901.5

 
1,968.3

 
 
 
 
 
 
 
2,004.2

 
 
 
 
 


4


 
 
 
 
 
 
 
 
 
 
Average Coal Quality (As received)
Mine/Reserve
 
Type of Mine
 
Coal Formation or
Coal Seam(s)
 
Average Seam
Thickness (feet)
 
Average
Depth (feet)
 
BTUs/lb
 
Sulfur (%)
 
Ash (%)
 
Moisture (%)
Unconsolidated Mines
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Freedom Mine (c)
 
Surface Lignite
 
Beulah-Zap Seam
 
18

 
130

 
6,700

 
0.90
%
 
9
%
 
36
%
Falkirk Mine (c)
 
Surface Lignite
 
Hagel A&B, Tavis
Creek Seams
 
8

 
90

 
6,200

 
0.62
%
 
11
%
 
38
%
South Hallsville No. 1 Mine (c)
 
Surface Lignite
 
(e)
 
(e)

 
(e)

 
(e)

 
(e)

 
(e)

 
(e)

Five Forks Mine (c)
 
Surface Lignite
 
(e)
 
(e)

 
(e)

 
(e)

 
(e)

 
(e)

 
(e)

Marshall Mine (c)
 
Surface Lignite
 
(e)
 
(e)

 
(e)

 
(e)

 
(e)

 
(e)

 
(e)

Eagle Pass Mine (c)
 
Surface
Sub-bituminous
 
(e)
 
(e)

 
(e)

 
(e)

 
(e)

 
(e)

 
(e)

Liberty Mine (c)
 
Surface Lignite
 
(e)
 
(e)

 
(e)

 
(e)

 
(e)

 
(e)

 
(e)

Coyote Creek Mine (c)
 
Surface Lignite
 
Beulah-Zap Seam
 
10

 
95

 
6,900

 
0.98
%
 
8
%
 
36
%
Navajo Mine (c)
 
Surface
Sub-bituminous
 
(e)
 
(e)

 
(e)

 
(e)

 
(e)

 
(e)

 
(e)

Consolidated Mines
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
Centennial Natural Resources
 
Surface Bituminous
 
Black Creek, C1, C2, C3, New Castle, Mary Lee, Jefferson, American, Nickel Plate, Pratt Seams
 
1.75

 
178

 
13,226

 
2.00
%
 
10
%
 
4
%
Red Hills Mine
 
Surface Lignite
 
C, D, E, F, G, H Seams
 
3.6

 
150

 
5,200

 
0.60
%
 
14
%
 
43
%
Undeveloped Mines
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
North Dakota
 

 
Fort Union Formation
 
13

 
130

 
6,500

 
0.8
%
 
8
%
 
38
%
Texas
 

 
Wilcox Formation
 
5

 
120

 
6,800

 
1.0
%
 
16
%
 
30
%
Eastern (l)
 

 
Freeport & Kittanning Seams
 
4

 
400

 
12,070

 
3.3
%
 
12
%
 
3
%
Mississippi
 

 
Wilcox Formation
 
5

 
130

 
5,200

 
0.6
%
 
13
%
 
44
%


(a)
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 30% of the proven and probable reserves.
(b)
NACoal’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 a 200 foot grid and inverse distance to the second power as an interpolator for all of NACoal's reserves, except for the reserves of Centennial where a 50 foot grid was used. As such, all reserves are considered proven (measured) within NACoal’s reserve estimate. None of NACoal’s coal reserves have been reviewed by independent experts.
(c)
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.
(d)
Although the term of the existing coal sales agreement terminates in 2022, the term may be extended for three additional periods of five years, or until 2037, at the option of Coteau.
(e)
The reserves are owned and controlled by the customer and, therefore, have not been listed in the table.
(f)
The contract for development of this mine was executed during 2009, and less than 0.1 million tons were sold in 2014.
(g)
The contract for development of this mine was executed during 2009, and no sales occurred during 2014.
(h)
The contract for development of this mine was executed during 2010, and no sales occurred during 2015 or 2014.
(i)
The term of this contract is 40 years, commencing on the date of commercial deliveries, which is anticipated to occur during 2016.
(j)
The contract for development of this mine was executed during 2012, and no sales occurred during 2015 or 2014.
(k)
The contract for operation of this mine was executed during 2015, and no sales occurred during 2015.
(l)
The majority of the coal produced was sold to a single customer under contract through the third quarter of 2015.
(m)
The proven and probable reserves included in the table do not include coal that is leased to others. NACoal had 100.5 million tons and 105.2 million tons in 2015 and 2014, respectively, of Eastern Undeveloped Mines with leased coal committed under contract.

5





6


Unconsolidated Mines
Freedom Mine — The Coteau Properties Company
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 275 leases granting the right to mine approximately 34,510 acres of coal interests and the right to utilize approximately 22,563 acres of surface interests. In addition, Coteau owns in fee 32,356 acres of surface interests and 4,265 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 Freedom Mine generally produces between 13 million and 15 million tons of lignite coal annually. The mine started delivering coal in 1983. All production from the mine is sold to Dakota Coal Company, a wholly owned subsidiary of Basin Electric Power Cooperative. Dakota Coal Company then sells the coal to Great Plains Synfuels Plant, Antelope Valley Station and Leland Olds Station, all of which are affiliates of Basin Electric Power Cooperative.
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, 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 290 leases granting the right to mine approximately 45,999 acres of coal interests and the right to utilize approximately 24,607 acres of surface interests. In addition, Falkirk owns in fee 40,339 acres of surface interests and 1,270 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 Falkirk Mine generally produces between 7 million and 9 million tons of lignite coal annually primarily for the Coal Creek Station, an electric power generating station owned by Great River Energy. Commencing in the second half of 2014, Falkirk began delivering coal to Spiritwood Station, another electric power generating station owned by Great River Energy. Annual deliveries to Spiritwood Station are expected to average approximately 500,000 tons. The mine started delivering coal in 1978.
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, 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.
The South Hallsville No. 1 Mine has two active pits generally producing between 3 million and 5 million tons of lignite coal annually based upon Southwestern Electric Power Company’s demand for its Henry W. Pirkey Plant. The mine started delivering coal in 1985.
Five Forks Mine — Demery Resources Company, LLC
The Five Forks Mine, operated by Demery, is located approximately three miles north of Creston, Louisiana on State Highway 153. Access to the Five Forks Mine is by means of a gravel road. Demery commenced delivering coal to its customer in 2012 and is expected to reach full production levels in 2017. 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.

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Marshall Mine — Caddo Creek Resources Company, LLC
The Marshall Mine, operated by Caddo Creek, commenced production in late 2014 and is located approximately ten miles south of Marshall, Texas on FM-1186. Access to the Marshall Mine is by means of a paved road. Caddo Creek has no title, claim, lease or option to acquire any of the reserves at the Marshall Mine. Marshall Mine, LLC controls all of the reserves within the Marshall Mine.
Eagle Pass Mine — Camino Real Fuels, LLC

The Eagle Pass Mine, operated by Camino Real, commenced production in October 2015 and is located approximately six miles north of Eagle Pass, Texas on State Highway 1588. Access to the Eagle Pass Mine is by means of a paved road. Camino Real has no title, claim, lease or option to acquire any of the reserves at the Eagle Pass Mine. Dos Republicas Coal Partnership controls all of the reserves within the Eagle Pass Mine.
Liberty Mine — Liberty Fuels Company, LLC

The Liberty Mine, operated by Liberty, is located approximately 20 miles north of Meridian, Mississippi off State Highway 493. Liberty commenced production in 2013 and is expected to increase production levels gradually with expected full production levels reached in 2023. Liberty has no title, claim, lease or option to acquire any of the reserves at the Liberty Mine. Mississippi Power Company controls all of the reserves within the Liberty Mine.
Coyote Creek Mine - Coyote Creek Mining Company, LLC

The Coyote Creek Mine,operated by Coyote Creek, is in the development stage and 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 graveled road extending west off of State Highway 49. Coyote Creek holds a sublease to 85 leases granting the right to mine approximately 7,809 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. Substantially all of these leases were acquired during the years 2010 through 2012 and have lease terms for a period sufficient to meet Coyote Creek's contractual production requirements.

In mid-2016, the Coyote Creek Mine is expected to begin coal deliveries to the Coyote Station owned by Otter Tail Power Company, Northern Municipal Power Agency, Montana-Dakota Utilities Company and Northwestern Corporation.

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

The Navajo Mine, to be operated by Bisti, 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. The Navajo Nation controls all of the reserves within the Navajo Mine.
Consolidated Mines
Centennial Natural Resources
Centennial's mines are located about 12 miles east and southeast of the city of Jasper in Walker County, Alabama, about 20 miles southeast of the city of Jasper in Jefferson County, Alabama, and about 15 miles northwest of the City of Jasper in Winston County, Alabama. The main entrances to the Walker County, Alabama mines are accessed by means of a half-mile graveled road extending south off Sipsey Road and a half-mile graveled road extending west off Cordova Gorgas Road. The main entrance to the Jefferson County, Alabama mine is accessed by means of a three-mile paved section of Porter Road extending south off Snowville - Brent

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Road. The main entrance to the Winston County, Alabama mine is accessed by means of a quarter-mile gravel road extending west off County Road 21. The reserves within the Centennial mines are controlled by Centennial.
Centennial and its affiliate, North American Coal Royalty Company, own in fee approximately 5,339 acres of coal interests and approximately 2,397 acres of surface interests. Centennial holds leases granting the right to mine approximately 12,142 acres of coal interests and the right to utilize approximately 20,046 acres of surface interests. The majority of the leases held by Centennial were originally acquired between 2000 and 2010 with terms that can be extended by the continuation of mining.
Structurally, the reserves for the Centennial mines are located within the Warrior Coal Basin. The strata that underlies and outcrops in this region is of the Pottsville Formation of the Pennsylvanian Age. The Warrior Basin is the southernmost of a series of Pennsylvanian basins of the Appalachian Plateau. The Pottsville Formation in this area consists of thin to thick bedded sandstones, siltstones, shales, clays and coal seams. This sequence of clastic sediments is representative of a deltaic depositional environment. Structurally, the Warrior Basin is formed by a large gentle syncline that extends from north-central Mississippi in the west to north-central Alabama in the east. The syncline is tilted southwestward with a regional dip of 30 to 200 feet per mile. Toward the interior of the Warrior Basin, the regional southwest dip of Pottsville strata is modified by a series of three synclines and two anticlines. Of these, the major structural areas are the Warrior and Coalburg synclines, and the Sequatchie anticline. The fold axes are parallel to the Appalachian system in a northeast-southwest direction and plunge to the southwest with the regional dip.
Red Hills Mine — Mississippi Lignite Mining Company
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 4,590 acres of surface interest and 2,198 acres of coal interests. MLMC holds leases granting the right to mine approximately 7,731 acres of coal interests and the right to utilize approximately 6,507 acres of surface interests. MLMC holds subleases under which it has the right to mine approximately 308 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 Red Hills Mine generally produces approximately 3 million to 4 million tons of lignite coal annually for use at the Red Hills Power Plant. The mine started delivering coal in 2000.
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.
Florida Dragline Operations — The North American Coal Corporation
NACoal’s Florida Dragline Operations operate draglines to mine limerock at the following quarries in Florida pursuant to mining services agreements with the quarry owners:
Quarry Name
Location
Quarry Owner
Year NACoal Started Dragline Operations
White Rock Quarry — North
Miami
WRQ
1995
White Rock Quarry — South
Miami
WRQ
2005
Krome Quarry
Miami
Cemex
2003
Alico Quarry
Ft. Myers
Cemex
2004
FEC Quarry
Miami
Cemex
2005
SCL Quarry
Miami
Cemex
2006

Vecellio & Grogan, Inc., d/b/a White Rock Quarries (“WRQ”) and Cemex S.A.B. de C.V. (“Cemex”) control all of the limerock reserves within their respective quarries. WRQ and Cemex perform drilling programs occasionally for the purpose of redefining the bottom of the limerock bed.
Access to the White Rock Quarry is by means of a paved road from 122nd Avenue and access to the Krome Quarry is by means of a paved road from Krome Avenue. Access to the FEC Quarry is by means of a paved road from NW 118th Avenue and access to the Alico Quarry is by means of a paved road from Alico Road. Access to the SCL Quarry is by means of a paved road from NW 137th Avenue. Florida Dragline Operations have no title, claim, lease or option to acquire any of the reserves at the White Rock Quarry (North and South), the FEC Quarry, the Krome Quarry, the SCL Quarry or the Alico Quarry.

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North American Coal Royalty Company
No operating mines currently exist on the undeveloped reserves in North Dakota, Texas and Mississippi. North American Coal Royalty Company receives certain royalty payments from third parties for production or advance royalty payments for oil and gas, as well as for coal reserves located in Alabama, Ohio, Pennsylvania, North Dakota, Louisiana, Texas and Mississippi.
General Information about the Mines
Leases. The leases held by Coteau, Falkirk, Coyote Creek and MLMC have a variety of continuation provisions, but generally permit the leases to be continued beyond their fixed terms. Under the terms of the leases held by these subsidiaries, each respective subsidiary expects that coal mined pursuant to its leases will be available to meet its production requirements. Centennial holds the mining rights to the reserves within its mines through fee ownership, and leases and licenses from the coal and surface owners.
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, Liberty Mine, Coyote Creek Mine or Red Hills Mine. Bisti will become an operator of NTEC's Navajo Mine, which is currently operated by a third party.
Exploration and Development. NACoal has one mine, Coyote Creek Mine, currently in development. The Centennial mines have ceased production as of December 31, 2015. With the exception of Coyote Creek and Centennial, all other mines are well past the exploration stage. Additional pit development is under way at each 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 six years of the current pit. Drilling beyond the six-year horizon ranges from 1,000 to 2,000-foot centers. Drilling is conducted every other year to stay current with the advance of mining operations. Geological evaluation is in process at all locations.
Facilities and Equipment. The facilities and equipment for each of the 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 draglines is provided by the Pirkey Power Plant. The remainder of the equipment generally is powered by diesel or gasoline.


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The total cost of the property, plant and equipment, net of applicable accumulated amortization, depreciation and impairment as of December 31, 2015 is set forth in the chart below:
Mine
 
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
 
$
202.5

Falkirk Mine — The Falkirk Mining Company
 
$
98.6

South Hallsville No. 1 Mine — The Sabine Mining Company
 
$
174.7

Five Forks Mine — Demery Resources Company, LLC
 
$

Marshall Mine — Caddo Creek Resources Company, LLC
 
$

Eagle Pass Mine — Camino Real Fuels, LLC
 
$

Liberty Mine — Liberty Fuels Company, LLC
 
$
19.0

Coyote Creek Mine — Coyote Creek Mining Company, LLC
 
$
164.8

Consolidated Mining Operations
 
 
Red Hills Mine — Mississippi Lignite Mining Company
 
$
45.7

Centennial (a)
 
$
12.9

Florida Dragline Operations — The North American Coal Corporation
 
$
2.7

(a) Does not include $17.5 million of Centennial's mine machinery and equipment that is included in "Assets held for sale" on the Consolidated Balance Sheet at December 31, 2015. See Note 3 to the Consolidated Financial Statements for further discussion of assets held for sale.
Predominantly all of Demery, Caddo Creek, Camino Real and Liberty's machinery and equipment is owned by NACoal’s customers. A substantial portion of MLMC’s machinery, trucks and equipment is rented under operating leases and one of Centennial's draglines is under a capital lease. All other draglines were purchased used and have been or are expected to be updated with the latest technology.
Government Regulation
NACoal’s coal mining operations and dragline mining services 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 others, the reclamation and restoration of properties after mining operations, 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 NACoal’s coal mining operations.
Numerous governmental permits and approvals are required for coal mining operations. NACoal or one of its subsidiaries holds or will hold the necessary permits at all of NACoal’s coal mining operations except Demery, Caddo Creek, Bisti and Camino Real, where NACoal’s customers hold the permits, and Centennial, where a coal reserve owner and a contract miner hold certain 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 NACoal to operate Centennial, Caddo Creek, Demery, Bisti and Camino Real; however, the Company cannot be certain that these third parties will be able to maintain all such permits in the future.
At the coal mining operations where NACoal holds the permits, NACoal 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.
The limerock quarries where NACoal provides dragline mining services are owned and operated by NACoal’s customers.
Some laws, as discussed below, place many requirements on NACoal’s coal mining operations and the limerock quarries where NACoal provides dragline mining services. Federal and state regulations require regular monitoring of NACoal’s operations to ensure compliance.

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Mine Health and Safety Laws
The Federal Mine Safety and Health Act of 1977 imposes safety and health standards on all coal 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
NACoal’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 (the “Clean Water Act”);
the Resource Conservation and Recovery Act; and
the Comprehensive Environmental Response, Compensation and Liability Act.
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. NACoal has ongoing training, compliance and permitting programs to ensure compliance with such environmental laws.
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. All of the states where NACoal 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 NACoal’s 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 part of SMCRA, imposes a fee on certain coal mining operations. The proceeds are 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, where necessary. These obligations are unfunded with the exception of the final mine closure costs for the Coyote Creek Mine, which will be funded throughout the production stage.
SMCRA stipulates compliance with many other major environmental programs, including the CAA and Clean Water Act. 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 Office of Surface Mining Reclamation and Enforcement ("OSM") are engaged in a series of rulemakings and other administrative actions under the Clean Water Act and other statutes that are directed at reducing the impact of coal mining operations on water bodies. Currently, these initiatives are primarily with respect to mining operations in the Appalachian region, especially on mountaintops.
The Company does not believe there is any significant risk to NACoal’s ability to maintain its existing mining permits or its ability to acquire future mining permits for its mines.

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Clean Air Act and Clean Power Plan ("CPP")

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 could be to reduce demand for coal. Any 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. NACoal’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 response to a court remand of earlier rules to control the regional dispersion of sulfur dioxide and nitrogen oxides from coal-fired power plants and their impacts of downwind NAAQS areas, 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. On August 21, 2012, the U.S. Court of Appeals struck down the CSAPR rule, effectively eliminating the new additional emission restrictions. The EPA subsequently appealed to the U.S. Supreme Court, which overturned the lower court ruling on April 29, 2014. EPA began implementation of the rule January 1, 2015, when Phase I emission reductions in sulfur dioxide and nitrogen dioxide became effective. Phase II reductions become effective on January 1, 2017. On November 16, 2015, the EPA proposed an update to the CSAPR. In this update, the EPA proposes more stringent Phase II reductions in nitrogen oxide emissions. Some questions regarding the rule remain unresolved and additional litigation is pending.

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 by December 2007; however, many states did not meet that deadline.

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 remaining litigation and the uncertainty around the New Source Review Program rules could adversely impact demand for coal. Regardless of the outcome of litigation on either rule, stricter controls on emissions of sulfur dioxide, nitrogen oxide and mercury are likely. Any such 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. In Michigan vs. Environmental Protection Agency, the U.S. Circuit Court of Appeals for the District of

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Columbia affirmed MATS, and that ruling was appealed. On June 29, 2015, the U.S. Supreme Court remanded the rule back to the Circuit Court, directing it to address deficiencies in the EPA’s MATS cost-benefit analysis. The Circuit Court directed the EPA to re-evaluate costs and benefits associated with the rule. On December 1, 2015, the EPA published a supplemental finding that consideration of costs does not alter the agency's original conclusion to regulate mercury and other air toxics through this rule. The EPA is expected to publish a final finding in the spring of 2016.

NACoal’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 could raise the price of coal-generated electricity, making coal-fired power less competitive with other sources of electricity, thereby reducing demand for coal. In addition, NACoal's power generation customers may choose to close coal-fired generation units or to postpone or cancel plans to add new capacity, in light of these costs and the limited time available for compliance with the requirements and the prospects of the imposition of additional future requirements on emissions from coal-fired units. If NACoal's customers cannot offset the cost to control certain regulated pollutant emissions by lowering the costs of delivery of its coal on an energy equivalent basis or if NACoal'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 public and scientific attention and a considerable amount of legislative and regulatory attention in the United States. The U.S. Congress has considered climate change legislation that would reduce 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 some of its 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 “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 has begun to establish 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. On June 26, 2012, the U.S. Court of Appeals - DC Circuit upheld this finding. Based on this finding, in 2012 the EPA published a New Source Performance Standard for greenhouse gases, emitted from future new power plants. This was withdrawn and subsequently reissued in January 2014. On June 2, 2014, the EPA proposed new regulations limiting carbon dioxide emissions from existing power plants. On June 18, 2014, the EPA also issued a proposed carbon dioxide emission regulation for reconstructed and modified power plants, which addresses carbon dioxide emissions limits for power plants subsequent to modification. On August 3, 2015, President Obama and the EPA announced the CPP, which includes final emission guidelines for states to follow in developing plans to reduce GHG emissions from existing fossil fuel-fired electric generating units ("EGUs") as well as limits on GHG emission rates for new, modified and reconstructed EGUs. Under the CPP, nationwide carbon dioxide emissions would be reduced by 32% from 2005 levels by 2030 with emissions reductions scheduled to be phased in between 2022 and 2030. On February 9, 2016, the U.S. Supreme Court granted a stay of the CPP pending resolution of litigation challenging the CPP. The CPP, though stayed, would require states to frame initial SIPs by September 6, 2016. The EPA has indicated it will grant states two additional years to submit final SIPs, if justified (to be submitted by September 6, 2018). Enactment of laws and passage of regulations regarding GHG emissions by the U.S. or some of its 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 reducing generation or closing coal-fired power plants and/or switching from coal to other fuel sources and could have a materially adverse effect on NACoal’s business, financial condition and results of operations.

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. Because the first Protocol commitment period ended in 2012, an amendment to extend the Kyoto Protocol was adopted in Doha, Qatar on December 8, 2012. The U.S. is not a signatory to the amendment. Even though the U.S. has not accepted these international GHG limiting treaties or enacted domestic legislation to control GHGs, 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. On November 11, 2014, President Obama and Chinese President Xi Jinping jointly announced each nation's intentions to limit GHG emissions. These were non-binding statements of intent. As a successor to the Kyoto Protocol, on December 12, 2015, international negotiators finalized the Paris Agreement under the United Nations Framework

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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. Because this agreement has no legally binding GHG reduction requirements, the President believes this does not constitute a treaty requiring Senate ratification. He is expected to sign this as a sole executive agreement. Although not legally binding, the President may use the Paris Agreement as support for continued regulatory actions limiting GHG’s. The 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-fueled EGUs due to the potential for increased air emissions. Such opposition, as well as any corporate or investor policies against coal-fired EGUs, could also reduce the demand for NACoal’s coal. Further, policies limiting available financing for the development of new coal-fueled EGUs could adversely impact the global demand for coal in the future. The potential impact on NACoal 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 us to predict reasonably the impact that any such laws, regulations or other policies may have on NACoal’s business, financial condition and results of operations. However, such impacts could have a material adverse effect on NACoal’s business, financial condition and results of operations.

The Company believes NACoal 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 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.

Federal and state regulations establish standards that prohibit the diminution of water quality. 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 NACoal has obtained all permits required under the Clean Water Act and corresponding state laws and is in compliance with such permits. In many instances, mining operations require securing Clean Water Act authorization or a permit from the U.S. Army Corps of Engineers for operations in waters of the United States.

Bellaire Corporation, a wholly owned non-operating subsidiary of the Company (“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 and has accrued a liability of $17.4 million as of December 31, 2015 related to these treatment operations.

In connection with Bellaire's normal permit renewal with the Pennsylvania Department of Environmental Protection ("DEP"), Bellaire was notified during 2004 that in order to obtain renewal of the permit Bellaire would be required to establish a mine water treatment trust (the "Trust"). On October 1, 2010, Bellaire executed a Post-Mining Treatment Trust Consent Order and Agreement with the DEP which established the Trust to provide a financial assurance mechanism in order to assure the long-term treatment of post-mining discharges. Bellaire funded the Trust with $5.0 million. See Note 7 and Note 10 for further information on the Trust.
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. These standards may

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raise the cost for CCR disposal at coal-fired power plants, making them less competitive, and may 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 OSM. Currently, the OSM is developing rules to address the use of CCRs on coal mine sites. The outcome of these rulemakings, and any subsequent actions by EPA and OSM, could impact those NACoal operations that beneficially use CCRs. If NACoal were unable to beneficially use CCRs, its revenues for disposing of CCRs from its customers may decrease and its costs may increase due to the purchase of alternative materials for beneficial uses.
Comprehensive Environmental Response, Compensation and Liability Act
The Comprehensive Environmental Response, Compensation and Liability Act and similar state laws create liabilities for the investigation and remediation of releases of hazardous substances into the environment and for damages to natural resources. The Company must also comply with reporting requirements under the Emergency Planning and Community Right-to-Know Act and the Toxic Substances Control Act.
From time to time, the Company has been the subject of administrative proceedings, litigation and investigations relating to environmental matters.
The extent of the liability and the cost of complying with environmental laws cannot be predicted with certainty due to many factors, including the lack of specific information available with respect to many sites, the potential for new or changed laws and regulations, the development of new remediation technologies and the uncertainty regarding the timing of work with respect to particular sites. As a result, the Company may incur material liabilities or costs related to environmental matters in the future, and such environmental liabilities or costs could materially and adversely affect the Company’s results of operations and financial condition. In addition, there can be no assurance that changes in laws or regulations would not affect the manner in which NACoal is required to conduct its operations.
Competition
The coal industry competes with other sources of energy, particularly oil, gas, hydro-electric power and nuclear power. In addition, it competes with subsidized green energy projects, such as biofuels, wind and solar projects. 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 and the impact of federal and state energy policies. The ability of NACoal to market and develop its reserves will depend upon the interaction of these factors.
Based on industry information, NACoal believes it was one of the ten largest coal producers in the U.S. in 2015 based on total coal tons produced.
Employees
As of December 31, 2015, NACoal had approximately 1,900 employees, including approximately 1,550 employees at the unconsolidated mines. None of NACoal’s employees are unionized as of December 31, 2015. NACoal believes its current labor relations with employees are satisfactory.

B. Hamilton Beach Brands
General
HBB is a leading designer, marketer and distributor of small electric household and specialty housewares appliances, as well as commercial products for restaurants, bars and hotels. HBB’s products are marketed primarily to retail merchants and wholesale distributors.
Sales and Marketing
HBB designs, markets and distributes a wide range of small electric household and specialty housewares appliances, including, but not limited to, blenders, can openers, coffeemakers, food processors, indoor electric grills, irons, mixers, slow cookers, toasters and toaster ovens. In addition, HBB designs, markets and distributes commercial products for restaurants, bars and hotels. HBB generally markets its “better” and “best” products under the Hamilton Beach® brand and uses the Proctor Silex® brand for the “good” and opening price point products. HBB entered the "only-the-best" market with licensing agreements to sell Jamba® branded blenders and juicing products and a line of counter top appliances and kitchen tools under the Wolf Gourmet® brand. As a result of the 2014 Weston Brands acquisition, HBB now markets a range of game and garden food processing equipment including, but not limited to, meat grinders, bag sealers, dehydrators and meat slicers under the Weston®

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brand as well as several private label brands. HBB supplies additional private label products on a limited basis throughout North America.
HBB markets its retail products primarily in North America, but also sells products in South America, Asia and other selected markets. HBB commercial products are sold worldwide. Retail sales in North America are generated predominantly by a network of inside sales employees to mass merchandisers, e-commerce retailers, national department stores, variety store chains, drug store chains, specialty home retailers, distributors and other retail outlets. Wal-Mart accounted for approximately 32%, 33% and 31% of HBB’s revenues in 2015, 2014 and 2013, respectively. HBB’s five largest customers accounted for approximately 52%, 56% and 55% of HBB’s revenues for the years ended December 31, 2015, 2014 and 2013, respectively. The loss of or significant reduction in sales to any key customer could result in significant decreases in HBB’s revenue and profitability and its ability to sustain or grow its business.
Sales promotion activities are primarily focused on cooperative advertising. In addition, HBB promotes certain of its innovative products through the use of television, internet and print advertising. HBB also licenses certain of its trademarks to various licensees primarily for use with microwaves, compact refrigerators, cookware, kitchen tools and gadgets and full-size household vacuums.
Because of the seasonal nature of the markets for small electric appliances, HBB’s management believes backlog is not a meaningful indicator of performance and is not a significant indicator of annual sales. Backlog represents customer orders, which may be cancelled at any time prior to shipment. Backlog for HBB was approximately $16.0 million and $17.5 million at December 31, 2015 and 2014, respectively.
HBB’s warranty program to the consumer consists generally of a limited warranty lasting for varying periods of up to ten years for electric appliances, with the majority of products having a warranty of one year. Under its warranty program, HBB may repair or replace, at its option, those products returned under warranty.
The market for small electric household and specialty housewares appliances is highly seasonal in nature. Revenues and operating profit for HBB are traditionally greater in the second half of the year as sales of small electric appliances to retailers and consumers increase significantly with the fall holiday-selling season. Because of the seasonality of purchases of its products, HBB generally uses a substantial amount of cash or short-term debt to finance inventories and accounts receivable in anticipation of the fall holiday-selling season.
Patents, Trademarks, Copyrights and Licenses
HBB holds patents and trademarks registered in the U.S. and foreign countries for various products. HBB believes its business is not dependent upon any individual patent, copyright or license, but that the Hamilton Beach® and Proctor Silex® trademarks are material to its business.
Product Design and Development
HBB spent $9.6 million, $9.6 million and $8.1 million in 2015, 2014 and 2013, respectively, on product design and development activities.
Key Suppliers and Raw Material
HBB’s products are supplied to its specifications by third-party suppliers located primarily in China. HBB does not maintain long-term purchase contracts with suppliers and operates mainly on a purchase order basis. HBB generally negotiates purchase orders with its foreign suppliers in U.S. dollars. A weakening of the U.S. dollar against local currencies could result in certain non-U.S. manufacturers increasing the U.S. dollar prices for future product purchases.
During 2015, HBB purchased 99% of its finished products from suppliers in China. HBB purchases its inventory from approximately 40 suppliers, two of which represented more than 10% of purchases during the year ended December 31, 2015. HBB believes the loss of any one supplier would not have a long-term material adverse effect on its business because there are adequate supplier choices available that can meet HBB’s production and quality requirements. However, the loss of a supplier could, in the short term, adversely affect HBB’s business until alternative supply arrangements are secured.
The principal raw materials used by HBB’s third-party suppliers to manufacture its products are plastic, glass, steel, copper, aluminum and packaging materials. HBB believes adequate quantities of raw materials are available from various suppliers.

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Competition
The small electric household appliance industry does not have onerous entry barriers. As a result, HBB competes with many small manufacturers and distributors of housewares products. Based on publicly available information about the industry, HBB believes it is one of the largest full-line distributors and marketers of small electric household and specialty housewares appliances in North America based on key product categories.
Besides North America, HBB also competes to a lesser degree in Europe through its commercial product lines, and in South America and China. The competition in these geographic markets is more fragmented than in North America, and HBB is not yet a significant participant in these markets.
As retailers generally purchase a limited selection of small electric appliances, HBB competes with other suppliers for retail shelf space. HBB conducts consumer advertising for the Hamilton Beach® brand and the Weston® brand. HBB believes the principal areas of competition with respect to its products are product design and innovation, quality, price, product features, supply chain excellence, merchandising, promotion and warranty.
Government Regulation
HBB is subject to numerous federal and state health, safety and environmental regulations. HBB’s management believes the impact of expenditures to comply with such laws will not have a material adverse effect on HBB.
As a marketer and distributor of consumer products, HBB is subject to the Consumer Products Safety Act and the Federal Hazardous Substances Act, which empower the U.S. Consumer Product Safety Commission (“CPSC”) to seek to exclude products that are found to be unsafe or hazardous from the market. Under certain circumstances, the CPSC could require HBB to repair, replace or refund the purchase price of one or more of HBB’s products, or HBB may voluntarily do so.
Throughout the world, electrical appliances are subject to various mandatory and voluntary standards, including requirements in some jurisdictions that products be listed by Underwriters’ Laboratories, Inc. (“UL”) or other similar recognized laboratories. HBB also uses Intertek Testing Services for certification and testing of compliance with UL standards, as well as other nation- and industry-specific standards. HBB endeavors to have its products designed to meet the certification requirements of, and to be certified in, each of the jurisdictions in which they are sold.

The Dodd-Frank Wall Street Reform and Consumer Protection Act of 2010 Section 1502 (the "Dodd-Frank Act") requires public companies to disclose whether certain minerals, commonly known as "conflict minerals," are necessary to the functionality or production of a product manufactured by those companies and if those minerals originated in the Democratic Republic of the Congo ("DRC") or an adjoining country. The ongoing implementation of these disclosure requirements by HBB could adversely affect the sourcing, availability, and pricing of minerals used in the manufacture of certain components used in HBB's products. In addition, the supply-chain due diligence investigation required by the conflict minerals rules requires expenditures of resources and management attention, regardless of the results of the investigation.
Employees
As of December 31, 2015, HBB’s work force, including Weston Brands, consisted of approximately 600 employees, none of whom are represented by unions except 16 hourly employees at HBB’s Picton, Ontario distribution facility. These employees are represented by an employee association which performs a consultative role on employment matters. None of HBB’s U.S. employees are unionized. HBB believes its current labor relations with both union and non-union employees are satisfactory.
C. Kitchen Collection
General
KC is a national specialty retailer of kitchenware operating under the Kitchen Collection® store name in outlet and traditional malls throughout the United States. 
Sales and Marketing
KC operated 229 retail stores as of December 31, 2015 under the Kitchen Collection® store name in outlet and traditional malls throughout the United States. The stores sell kitchenware from highly recognizable name-brands, including Hamilton Beach® and Proctor Silex®.

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Seasonality
Revenues and operating profit for KC are traditionally greater in the second half of the year as sales to consumers increase significantly with the fall holiday-selling season. Because of the seasonality of purchases of its products, KC incurs substantial short-term debt to finance inventories in anticipation of the fall holiday-selling season.
Product Design and Development
KC, a retailer, has limited expenditures for product design and development activities.
Product Sourcing and Distribution
KC purchases all inventory centrally, which allows KC to take advantage of volume purchase discounts and monitor controls over inventory and product mix. KC purchases its inventory from approximately 260 suppliers, one of which represented approximately 29% of purchases during the year ended December 31, 2015. No other supplier represents more than 10% of purchases. KC believes that the loss of any one supplier would not have a long-term material adverse effect on its business because there are adequate supplier choices available that can meet KC’s requirements. However, the loss of a supplier could, in the short term, adversely affect KC’s business until alternative supply arrangements are secured.
KC currently maintains its inventory for distribution to its stores at a distribution center located near its corporate headquarters in Chillicothe, Ohio.

KC plans to focus on comparable store sales growth within its smaller core store portfolio. KC expects to accomplish this by increasing closure rates through continued refinement of its format, ongoing review of specific product offerings, merchandise mix, store displays and appearance and enhancing customers' store experience through improved customer interactions. Increasing sales of higher-margin products will also continue to be a key focus, as well as continuing to evaluate and, as lease contracts permit, terminate or restructure leases for underperforming and loss-generating stores.
Competition
KC competes against a diverse group of retailers, including specialty stores, department stores, discount stores and internet and catalog retailers. The retail environment continues to be extremely competitive. Widespread Chinese sourcing of products allows many retailers to offer value-priced kitchen products.
KC believes there is growth potential in kitchenware retailing, but only through offering unique, high-quality products at prices affordable to most consumers. While a number of very low-end and very high-end kitchenware retailers participate in the marketplace, KC believes there is still an opportunity for stores offering mid-priced, high-quality kitchenware.
Patents, Trademarks, Copyrights and Licenses
KC holds a trademark registered in the U.S. for the Kitchen Collection® store name and believes that the trademark is material to its business.
Employees
As of December 31, 2015, KC’s work force consisted of approximately 1,100 employees. None of KC’s employees are unionized. KC believes its current labor relations with employees are satisfactory.
Item 1A. RISK FACTORS
North American Coal
Termination of or default under long-term mining contracts could materially reduce the Company's profitability.
Substantially all of NACoal's profits are derived from long-term mining contracts. The contracts for certain of NACoal's unconsolidated mines permit or obligate the customer under some conditions to acquire the assets or stock of the NACoal subsidiary for an amount roughly equal to book value. If any of NACoal's long-term mining contracts were terminated or if any of its customers were to default under the contracts, profitability could be materially reduced to the extent that NACoal is unable to find alternative customers at the same level of profitability.
NACoal's unconsolidated mines are subject to risks created by changes in customer demand, inflationary adjustments and tax rates.
The contracts with the unconsolidated mines’ customers provide for reimbursement to the Company at a price based on actual costs plus an agreed pre-tax profit per ton of coal sold or actual costs plus a management fee during the production stage.

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During the development stage, the contracts with the unconsolidated mines' customers (other than the Coyote Creek and Bisti customers) provide for reimbursement of actual costs incurred plus a monthly management fee. Coyote Creek's customer does not reimburse developments costs until the production stage, when certain deferred development costs are reimbursed over a 52-month period. Bisti's customer does not reimburse transition period costs until the production stage, when all transition costs are reimbursed over a 24-month period. During the production stage, the unconsolidated mines' customers pay the Company its per-ton profit or management 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 power plant outages, economic conditions or governmental regulations or comparable policies which may promote dispatch of power generated by renewables such as wind or solar ahead of coal, could have a material adverse effect on the Company's results of operations. Because of the contractual price formulas for the sale of coal and mining services by these unconsolidated mines, the profitability of these operations is also subject to fluctuations in inflationary adjustments (or lack thereof) that can impact the per ton profit or management fee paid for the coal and taxes applicable to NACoal's income on that coal. In addition, any changes in tax laws that eliminate benefits for percentage depletion would have a material adverse effect on the Company. These factors could materially reduce NACoal's profitability.
NACoal’s consolidated mining operations are subject to risks created by its capital investment in the mines, the costs of mining the coal and equipment costs, growing use of alternative generation that competes with coal fired generation, in addition to risks created by changes in customer demand, inflationary adjustments and tax rates.
The consolidated mining operations are comprised of MLMC, Centennial, dragline mining services, royalties from mineral leases to other mining and oil and gas companies, and other activities. The profitability of these consolidated mining operations is subject to the risk of loss of investment in these operations, changes in demand from customers, as well as increases in the cost of mining the coal and growing competition from alternative generation that competes with coal fired generation. At MLMC, the costs of mining operations are not reimbursed by customers. As such, increased costs at MLMC could materially reduce NACoal's profitability. In addition, MLMC sells lignite at contractually agreed upon coal 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 NACoal's profitability, as the decline in revenue will only be partially offset by the effect of lower diesel prices on production costs.
NACoal's operations are subject to changes in customer demand for any reason, including, but not limited to, fluctuations in demand due to unanticipated weather conditions, the emergence of unidentified adverse mining conditions, availability of alternative fuels such as natural gas at reduced prices making coal-fueled generation less competitive with natural gas-fueled generation, regulations or comparable policies which may promote dispatch of power generated by renewables such as wind or solar ahead of coal, planned and unplanned power plant outages, economic conditions, including economic conditions that adversely affect the demand for coal and steel, governmental regulations, inflationary adjustments and tax risks. In addition, any changes in tax laws that eliminate benefits for percentage depletion or eliminate the expensing of exploration and development costs could have a material adverse effect on NACoal's profitability.
Mining operations are vulnerable to weather and other conditions that are beyond NACoal's control.
Many conditions beyond NACoal's control can decrease the delivery, and therefore the use, of coal to NACoal's customers. These conditions include weather, adverse mining conditions, availability of alternative fuels such as natural gas at reduced prices making coal-fueled generation less competitive with natural gas-fueled generation, unexpected maintenance problems and shortages of replacement parts, which could significantly reduce the Company's profitability.
Government regulations could impose costly requirements on NACoal.
The coal mining industry is subject to extensive regulation by federal, state and local authorities on matters concerning the health and safety of employees, land use, 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. NACoal is required to prepare and present to federal, state or local authorities data pertaining to the impact the production 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. Compliance with these requirements may be costly and time-consuming and may delay commencement or continuation of development or production. New legislation and/or regulations and orders may materially adversely affect NACoal's mining operations or its cost structure. All of these factors could significantly reduce the Company's profitability. See “Item 1. Business — A. North American Coal — Government Regulation" on page 11 in this Form 10-K for further discussion.

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NACoal is subject to burdensome federal and state mining regulations.
Federal and state statutes require NACoal to restore mine property in accordance with specified standards and an approved reclamation plan, and require that NACoal obtain and periodically renew permits for mining operations. Regulations require NACoal to incur the cost of reclaiming current mine disturbance. Although the Company believes that appropriate accruals have been recorded for all expected reclamation and other costs associated with closed mines, future profitability would be adversely affected if accruals for these costs are later determined to be insufficient or if changed conditions, including adverse judicial proceedings or revised assumptions, require a change in these reserves.
The Clean Air Act and Clean Power Plan 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, CPP 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 CPP 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 could be 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 — A. North American Coal — Government Regulation" on page 11 in this Form 10-K for further discussion.
NACoal is subject to the high costs and risks involved in the development of new coal and dragline mining projects.
From time to time, NACoal seeks to develop new coal and dragline mining projects. The costs and risks associated with such projects can be substantial. In addition, any changes in tax laws that eliminate the expensing of exploration and development costs will increase the after-tax cost of building a mine and make the cost of coal less competitive with other power-generation fuels.
Estimates of NACoal'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.
NACoal estimates recoverable coal reserves based on engineering and geological data assembled and analyzed by internal and, less frequently, external engineers and geologists. NACoal'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 NACoal'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 NACoal's reserves may vary materially from estimates. Accordingly, NACoal's estimates may vary from 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.
Hamilton Beach Brands
HBB's business is sensitive to the strength of the North American retail markets and weakness in these markets could adversely affect its business.
The strength of the retail economy in the United States, and to a lesser degree in Canada and Mexico, has a significant impact on HBB's performance. Weakness in consumer confidence and poor financial performance by mass merchandisers,
e-commerce retailers, warehouse clubs, department stores or any of HBB's other customers could result in reduced revenues and profitability. A general slowdown in the retail sector could result in additional pricing and marketing support pressures on HBB.

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The market for HBB's products is highly seasonal and dependent on consumer spending, which could result in significant variations in the Company's revenues and profitability.
Sales of HBB's products are related to consumer spending. A downturn in the general economy or a shift in consumer spending away from small electric household and specialty housewares appliances could adversely affect its business. In addition, the market for small electric household and specialty housewares appliances is highly seasonal in nature. HBB generally recognizes a substantial portion of its sales in the last half of the year as sales of small electric appliances to retailers and consumers increase significantly with the fall holiday-selling season. Accordingly, quarter-to-quarter comparisons of past operating results of HBB are meaningful only when comparing equivalent time periods, if at all. Any economic downturn, decrease in consumer spending or shift in consumer spending away from small electric household and specialty housewares appliances may significantly reduce revenues and profitability.
HBB is dependent on key customers and the loss of, or significant decline in business from, one or more of its key customers could materially reduce its revenues and profitability and its ability to sustain or grow its business.
HBB relies on several key customers, which is discussed under “Item 1. Business — B. Hamilton Beach Brands — Sales and Marketing" on page 16 in this Form 10-K. Although HBB has long-established relationships with many customers, it does not have any long-term supply contracts with these customers, and purchases are generally made using individual purchase orders. A loss of any key customer could result in significant decreases in HBB's revenues and profitability and an inability to sustain or grow its business.
HBB must receive a continuous flow of new orders from its large, high-volume retail customers; however, it may be unable to continually meet the needs of those customers. In addition, failure to obtain anticipated orders or delays or cancellations of orders or significant pressure to reduce prices from key customers could impair its ability to sustain or grow its business.
As a result of dependence on its key customers, HBB could experience a material adverse effect on its revenues and profitability if any of the following were to occur:
the insolvency or bankruptcy of any key customer;
a declining market in which customers materially reduce orders or demand lower prices; or
a strike or work stoppage at a key customer facility, which could affect both its suppliers and customers.
If HBB were to lose, or experience a significant decline in business from, any major retail customer or if any major retail customers were to go bankrupt, HBB might be unable to find alternate distribution outlets.
HBB depends on third-party suppliers for the manufacturing of all of its products, which subjects the Company to risks, including unanticipated increases in expenses, decreases in revenues and disruptions in the supply chain.
HBB is dependent on third-party suppliers for the manufacturing of all of its products. HBB's ability to select reliable suppliers who provide timely deliveries of quality products will impact its success in meeting customer demand. Any inability of HBB's suppliers to timely deliver products that meet HBB's specifications or any unanticipated changes in suppliers could be disruptive and costly to the Company. Any significant failure by HBB to obtain quality products on a timely basis at an affordable cost or any significant delays or interruptions of supply would have a material adverse effect on the Company's revenues and profitability.
Because HBB's suppliers are primarily based in China, international operations subject the Company to additional risks including, among others:
currency fluctuations;
labor unrest;
potential political, economic and social instability;
lack of developed infrastructure;
restrictions on transfers of funds;
import and export duties and quotas;
changes in domestic and international customs and tariffs;

22


uncertainties involving the costs to transport products;
long distance shipping routes dependent upon a small group of shipping and rail carriers;
unexpected changes in regulatory environments;
regulatory issues involved in dealing with foreign suppliers and in exporting and importing products;
protection of intellectual property;
difficulty in complying with a variety of foreign laws;
difficulty in obtaining distribution and support; and
potentially adverse tax consequences.
The foregoing factors could have a material adverse effect on HBB's ability to maintain or increase the supply of products, which may result in material increases in expenses and decreases in revenues and profitability.
HBB is subject to foreign currency exchange risk
A portion of HBB's revenues is derived from international operations, and HBB anticipates that a portion of sales will continue to come from outside the U.S. in the future. HBB's international revenues may be adversely affected by fluctuations in foreign currency exchange rates. A discussion of the financial impact of exchange rate fluctuations is contained in "Item 7. Management’s Discussion and Analysis of Financial Condition and Results of Operations". Any hedging activities HBB engages in may only offset a portion of the adverse financial impact resulting from unfavorable changes in foreign currency exchange rates. HBB cannot predict with any certainty changes in foreign currency exchange rates or the degree to which HBB can mitigate these risks.
Increases in costs of products may materially reduce the Company's profitability.
Factors that are largely beyond the Company's control, such as movements in commodity prices for the raw materials needed by suppliers of HBB's products, may affect the cost of products, and HBB may not be able to pass those costs on to its customers. As an example, HBB's products require a substantial amount of plastic. Because the primary resource used in plastic is petroleum, the cost and availability of plastic varies to a great extent with the price of petroleum. When the prices of petroleum, as well as steel, aluminum and copper, increase significantly, they may materially reduce the Company's profitability.
The increasing concentration of HBB's small electric household and specialty housewares appliance sales among a few retailers and the trend toward private label brands could materially reduce revenues and profitability.
With the growing trend towards the concentration of HBB's small electric household and specialty housewares appliance sales among a few retailers, HBB is increasingly dependent upon fewer customers whose bargaining strength is growing as a result of this concentration. HBB sells a substantial quantity of products to mass merchandisers, e-commerce retailers, national department stores, variety store chains, drug store chains, specialty home retailers and other retail outlets. These retailers generally purchase a limited selection of small electric household and specialty housewares appliances. As a result, HBB competes for retail shelf space with its competitors. In addition, certain of HBB's larger customers use their own private label brands on household appliances that compete directly with some of HBB's products. As the retailers in the small electric household appliance industry become more concentrated, competition for sales to these retailers may increase, which could materially reduce the Company's revenues and profitability.
The small electric household, specialty housewares appliances and commercial appliance industry is consolidating, which could reduce HBB's ability to successfully secure product placements at key customers and limit its ability to sustain a cost competitive position in the industry.
Over the past several years, the small electric household, specialty housewares appliances and commercial appliance industry has undergone substantial consolidation, and further consolidation is likely. As a result of this consolidation, the small electric household, specialty housewares appliances and commercial appliance industry primarily consists of a limited number of large distributors. HBB’s ability to gain or maintain share of sales in the small electric household, specialty housewares appliances and commercial appliance industry or maintain or enhance HBB’s relationships with key customers may be limited as a result of actions by competitors, including as a result of increased consolidation in the small electric household, specialty housewares appliances and commercial appliance industry.

23


If HBB is unable to continue to enhance existing products, as well as develop and market new products, that respond to customer needs and preferences and achieve market acceptance, the Company may experience a decrease in demand for its products, which could materially reduce revenues and profitability, which have historically benefited from sales of new products.
One of HBB’s strategic initiatives is to enhance placements through consumer-driven innovative products to generate revenue growth. HBB may not be able to compete as effectively with competitors, and ultimately satisfy the needs and preferences of customers, unless HBB can continue to enhance existing products and develop new innovative products for the markets in which HBB competes. Product development requires significant financial, technological, and other resources. Product improvements and new product introductions also require significant research, planning, design, development, engineering, and testing at the technological and product process levels and HBB may not be able to timely develop and introduce product improvements or new products. Competitors' new products may beat HBB’s products to market, be higher quality or more reliable, be more effective with more features, obtain better market acceptance, or render HBB’s products obsolete. Any new products that HBB develops may not receive market acceptance or otherwise generate any meaningful revenues or profits for the Company relative to our expectations based on, among other things, commitments to fund advertising, marketing, promotional programs and development.
HBB's inability to compete effectively with competitors in its industry, including large established companies with greater resources, could result in lost market share and decreased revenues.
The small electric household, specialty housewares appliances and commercial appliance industry does not have substantial entry barriers. As a result, HBB competes with many small manufacturers and distributors of housewares products. Additional competitors may also enter this market and cause competition to intensify. For example, some of HBB's customers have expressed interest in sourcing, or expanding the extent of sourcing, small electric household and commercial appliances directly from manufacturers in Asia. The Company believes competition is based upon several factors, including product design and innovation, quality, price, product features, merchandising, promotion and warranty. If HBB fails to compete effectively with these manufacturers and distributors, it could lose market share and experience a decrease in revenues, which would adversely affect the Company's results of operations.
HBB also competes with established companies, a number of which have substantially greater facilities, personnel, financial and other resources. In addition, HBB competes with retail customers, who use their own private label brands, and importers and foreign manufacturers of unbranded products. Some competitors may be willing to reduce prices and accept lower profit margins to compete. As a result of this competition, HBB could lose market share and revenues.
Government regulations could impose costly requirements on HBB.
The SEC adopted conflict mineral rules under Section 1502 of Dodd-Frank on August 22, 2012. The rules require disclosure of the use of certain minerals, known as "conflict minerals," which are mined from the DRC and adjoining countries. HBB expects that it will incur additional costs and expenses, which may be significant, in order to comply with these rules, including (i) due diligence to verify the sources of such conflict minerals; and (ii) any changes that HBB may make to its products, processes, or sources of supply as a result of such diligence and verification activities. Since HBB's supply chain is complex, ultimately it may not be able to designate all products as "DRC conflict free" which may adversely affect its reputation with certain customers. In such event, HBB may also face difficulties in satisfying customers who require products purchased from HBB to be "DRC conflict free". If HBB is not able to meet such requirements, customers may choose not to purchase HBB products, which could adversely affect sales and the value of portions of HBB's inventory. Further, there may be only a limited number of suppliers offering products containing only DRC conflict free parts, components and subassemblies and, as a result, HBB cannot be sure that it will be able to satisfy its purchase requirements from such suppliers in sufficient quantities or at competitive prices. Any one or a combination of these various factors could harm HBB's business, and materially and adversely affect HBB's results of operations.
Kitchen Collection
The market for KC's products is highly seasonal and dependent on consumer spending, which could result in significant variations in the Company's revenues and profitability.
Sales of products sold at KC stores are subject to a number of factors related to consumer spending, including general economic conditions affecting disposable consumer income such as unemployment rates, business conditions, interest rates, levels of consumer confidence, energy prices, mortgage rates, the level of consumer debt and taxation. In addition, KC generally recognizes a substantial portion of its revenues and operating profit in the last half of the year as sales to consumers increase significantly with the fall holiday-selling season. Accordingly, any economic downturn, decrease in consumer

24


spending or a shift in consumer spending away from KC's products could significantly reduce, or cause significant variations in, KC's revenues and profitability.
KC faces an extremely competitive specialty retail market, and such competition could result in a reduction of KC's prices and loss of market share.
The retail market is highly competitive. KC competes against a diverse group of retailers, including specialty stores, department stores, discount stores and internet and catalog retailers. Widespread sourcing of products allows many retailers to offer value-priced kitchen products. Many of KC's competitors are larger and have significantly greater financial, marketing and other resources. This competition could result in the reduction of KC product prices and a loss of market share, revenues and profitability.
KC may not be able to forecast customer preferences accurately in its merchandise selections.
KC's success depends in part on its ability to anticipate the tastes of its customers and to provide merchandise that appeals to their preferences. KC's strategy requires merchandising staff to introduce products that meet current customer preferences and that are affordable and distinctive in quality and design. KC's failure to anticipate, identify or react appropriately to changes in consumer trends could cause excess inventories and higher mark-downs or a shortage of products and could harm KC's business and operating results.
KC depends on third-party suppliers for all of its products, which subjects KC to risks, including unanticipated increases in expenses, decreases in revenues and disruptions in the supply chain.
KC is dependent on third-party suppliers for all of its products. KC's inability to select reliable suppliers who provide timely deliveries of quality products could reduce its success in meeting customer demand. Any inability of KC's suppliers to timely deliver products or any unanticipated changes in suppliers could be disruptive and costly to KC. The loss of a supplier could, in the short term, adversely affect KC’s business until alternative supply arrangements are secured. In addition, KC may not be able to acquire desired merchandise in sufficient quantities on acceptable terms in the future. KC's business could also be adversely affected by delays in product shipments due to freight difficulties, strikes or other difficulties at its principal transport providers. Any significant failure by KC to obtain products on a timely basis at an affordable cost or any significant delays or interruptions of supply could have a material adverse effect on KC's profitability.
NACCO
The Company may be subject to risk relating to increasing cash requirements of certain employee benefits plans, which may affect its financial position.
Although the Company's defined benefit pension plans are frozen and no longer provide for the accrual of future benefits, the expenses recorded for, and cash contributions required to be made to its defined benefit pension plans are dependent on changes in market interest rates and the value of plan assets, which are dependent on actual investment returns. Significant changes in market interest rates, decreases in the value of plan assets or investment losses on plan assets may require the Company to increase the cash contributed to defined benefit pension plans which may affect its financial position.
The Company may become subject to claims under foreign laws and regulations, which may be expensive, time consuming and distracting.
Because the Company has employees, property and business operations outside of the United States, the Company is subject to the laws and the court systems of many jurisdictions. The Company may become subject to claims outside the U.S. for violations or alleged violations of laws with respect to the current or future foreign operations of NACoal and HBB. In addition, these laws may be changed or new laws may be enacted in the future. International litigation is often expensive, time consuming and distracting. As a result, any of these risks could significantly reduce the Company's profitability and its ability to operate its businesses effectively.
The Company is dependent on key personnel and the loss of these key personnel could significantly reduce its profitability.
The Company is highly dependent on the skills, experience and services of its key personnel and the loss of key personnel could have a material adverse effect on its business, operating results and financial condition. Employment and retention of qualified personnel is important to the successful conduct of the Company's business. Therefore, the Company's success also depends upon its ability to recruit, hire, train and retain additional skilled and experienced management personnel. The Company's inability to hire and retain personnel with the requisite skills could impair its ability to manage and operate its business effectively and could significantly reduce its profitability.

25


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.
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.
The Company relies heavily on information technology systems to operate websites; record and process transactions; respond to customer inquiries; manage inventory; purchase, sell and ship merchandise on a timely basis; and maintain cost-efficient operations. Given the significant number of transactions that are completed annually, it is vital to maintain constant operation of computer hardware and software systems and maintain cyber security. Despite the Company's cyber security 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. If the Company’s systems are damaged, or fail to function properly, NACCO may have to make monetary investments to repair or replace the systems and could endure delays in operations.
In addition, the Company regularly evaluates information technology systems and requirements and from time to time implements modifications and/or upgrades to the information technology systems that support its businesses. Modifications include replacing existing systems with successor systems, making changes to existing systems and acquiring new systems with new functionality. There are inherent risks associated with replacing and modifying these systems, including inaccurate system information, system disruptions and user acceptance and understanding. The Company believes it is taking appropriate action to mitigate the risks through disciplined adherence to program management, testing systems and user involvement, improving the resiliency of systems, as well as securing appropriate commercial contracts with third-party vendors but there can be no assurance that the Company's actions will be successful or sufficient.
Any material disruption or slowdown of the Company’s systems, including a disruption or slowdown caused by a security breach or the Company’s failure to successfully upgrade its systems, could cause information, including data related to customer orders, to be lost or delayed. Such a loss or delay could reduce demand and cause the Company’s sales and/or profitability to decline.
Through the Company’s sales and marketing activities and its business operations, the Company collects and stores confidential information and certain personal information from its customers, vendors and employees. For example, the Company handles, collects and stores personal information in connection with its customers purchasing products or services, or otherwise communicating or interacting with the Company. The Company also accepts payments using a variety of methods, including debit and credit cards, gift cards, electronic transfer of funds and others. 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, payment card associations, employees and other persons, any of which could have an adverse effect on the Company’s business, financial condition and results of operations.
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, 2015, accounted for approximately 25 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, 2015, accounted for the remaining voting power of the Company. As of December 31, 2015, certain members of the Company's extended founding family held approximately 35 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 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

26


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.

Item 1B. UNRESOLVED STAFF COMMENTS
None.
Item 2. PROPERTIES
A. NACCO
NACCO leases office space in Mayfield Heights, Ohio, a suburb of Cleveland, Ohio, which serves as its corporate headquarters.

B. NACoal

NACoal leases its corporate headquarters office space in Plano, Texas. NACoal’s proven and probable coal reserves and deposits (owned in fee or held under leases, which generally remain in effect until exhaustion of the reserves if mining is in progress) are estimated at approximately 2.0 billion tons (including the unconsolidated mining operations), all of which are lignite coal deposits, except for approximately 89.0 million tons of bituminous coal. Reserves are estimates of quantities of coal, made by NACoal’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 for NACoal’s properties are set forth on the table on pages 4 and 5 under “Item 1. Business — A. North American Coal — Sales, Marketing and Operations.”
C. Hamilton Beach Brands
The following table presents the principal distribution and office facilities owned or leased by HBB:
 
 
Owned/
 
 
Facility Location
 
Leased
 
Function(s)
Glen Allen, Virginia
 
Leased
 
Corporate headquarters
Geel, Belgium
 
(1)
 
Distribution center
Shenzhen, People's Republic of China
 
(1)
 
Distribution center
Mexico City, Mexico
 
Leased
 
Mexico sales and administrative headquarters
Tlalnepantla de Baz, Mexico
 
(1)
 
Distribution center
Olive Branch, Mississippi
 
Leased
 
Distribution center
Picton, Ontario, Canada
 
Leased
 
Distribution center
Southern Pines, North Carolina
 
Owned
 
Service center for customer returns; catalog distribution center; parts distribution center
Shenzhen, People's Republic of China
 
Leased
 
Administrative office
Markham, Ontario, Canada
 
Leased
 
Canada sales and administration headquarters
City of Sao Paulo, Sao Paulo, Brazil
 
Leased
 
Brazil sales and administrative headquarters
Jundiai, Sao Paulo, Brazil
 
(1)
 
Distribution center
Shanghai, People's Republic of China
 
Leased
 
Sales office
Shanghai, People's Republic of China
 
(1)
 
Distribution center
Independence, Ohio
 
Leased
 
Weston Brands sales office

(1)
This facility is not owned or leased by HBB. This facility is managed by a third-party distribution provider.
Sales offices are also leased in several cities in the United States, Canada, China and Mexico.

27


D. The Kitchen Collection

KC leases its corporate headquarters building and the KC warehouse/distribution facility in Chillicothe, Ohio. KC leases its retail stores. A typical Kitchen Collection® store is approximately 3,000 square feet. At December 31, 2015, there were 229 Kitchen Collection® stores.

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 Wall Street Reform and Consumer Protection Act and Item 104 of Regulation S-K is included in Exhibit 95 filed with this Form
10-K.


Item 4A. EXECUTIVE OFFICERS OF THE REGISTRANT
The information under this Item is furnished pursuant to Instruction 3 to Item 401(b) of Regulation S-K.
There exists no arrangement or understanding between any executive officer and any other person pursuant to which such executive officer was elected. Each executive officer serves until his or her successor is elected and qualified.
The following tables set forth the name, age, current position and principal occupation and employment during the past five years of the Company’s executive officers. Certain executive officers of the Company listed below are also executive officers for certain of NACCO's subsidiaries.

28


EXECUTIVE OFFICERS OF THE COMPANY
Name
 
Age
 
Current Position
 
Other Positions
 
 
 
 
 
 
 
Alfred M. Rankin, Jr.
 
74

 
Chairman, President and Chief Executive Officer of NACCO (from prior to 2011), Chairman of HBB (from prior to 2011), Chairman of KC (from prior to 2011), Chairman of NACoal (from prior to 2011)
 
Chairman, President and Chief Executive Officer of Hyster-Yale Materials Handling, Inc. (from September 2012). Chairman of Hyster-Yale Group ("Hyster-Yale"), formerly NACCO Materials Handling Group, Inc. ("NMHG")(from prior to 2011).
 
 
 
 
 
 
 
J.C. Butler, Jr.
 
55

 
Senior Vice President - Finance, Treasurer and Chief Administrative Officer of NACCO (from September 2012), President and Chief Executive Officer of NACoal (from July 2015), Assistant Secretary of HBB and KC (from November 2012)
 
From July 2014 to July 2015, Senior Vice President - Project Development, Administration and Mississippi Operations of NACoal. From prior to 2011 to June 2014, Senior Vice President - Project Development and Administration of NACoal. From prior to 2011 to September 2012, Vice President - Corporate Development and Treasurer of NACCO. From September 2011 to September 2012, Treasurer of NMHG.
 
 
 
 
 
 
 
Elizabeth I. Loveman
 
46

 
Vice President and Controller (from March 2014) and Principal Financial Officer (from June 2014)
 
From December 2012 to March 2014, Director of Financial Reporting of NACCO. From prior to 2011 to November 2012, Manager of Financial Reporting of OM Group, Inc.
 
 
 
 
 
 
 
John D. Neumann
 
40

 
Vice President, General Counsel and Secretary of NACCO (from September 2012), Vice President, General Counsel and Secretary of NACoal (from January 2011), Assistant Secretary of HBB and KC (from November 2012)
 
 
 
 
 
 
 
 
 
Miles B. Haberer
 
49

 
Associate General Counsel of NACCO (from October 2012), Associate General Counsel, Assistant Secretary of NACoal (from October 2012) and President of North American Coal Royalty Company (an NACoal subsidiary) (from September 2015)    
                                                        

 
From October 2013 to September 2015, Director-Land of NACoal. From October 2012 to September 2015, Assistant Secretary of NACCO. From prior to 2011 to October 2012, Partner, Hunton & Williams (law firm). 

 
 
 
 
 
 
 
Mary D. Maloney
 
54

 
Associate General Counsel, Assistant Secretary and Senior Director - Benefits & Human Resources of NACCO (from January 1, 2014), Associate General Counsel, Assistant Secretary and Senior Director - Benefits and Compensation of NACoal (from January 1, 2014)

 
From September 2012 to December 2013, Associate General Counsel and Assistant Secretary of Hyster-Yale and NMHG. From May 2012 to September 2012, Assistant General Counsel and Assistant Secretary of Hyster-Yale. From prior to 2011 to September 2012, Assistant General Counsel and Assistant Secretary of NACCO. From August 2011 to September 2012, Assistant Secretary of NMHG.
 
 
 
 
 
 
 
Jesse L. Adkins
 
33

 
Associate Counsel (from September 2012) and Assistant Secretary of NACCO (from November 2013), Associate Counsel (from August 2012) and Assistant Secretary (from May 2013) of NACoal                                
                          

 
From January 2011 to August 2012, Law Clerk, NACoal.

 
 
 
 
 
 
 
Thomas A. Maxwell
 
38

 
Director of Financial Planning and Analysis and Assistant Treasurer (from September 2015)

 
From January 2014 to September 2015, Senior Manager, Finance and Assistant Treasurer. From 2011 to January 2014, Manager of Financial Planning and Analysis.

29


PRINCIPAL OFFICERS OF THE COMPANY’S SUBSIDIARIES
A. NACOAL
Name
 
Age
 
Current Position
 
Other Positions
 
 
 
 
 
 
 
Carroll L. Dewing
 
59

 
Vice President - North Dakota, Texas and Florida Operations, Human Resources and External Affairs of NACoal (from July 2014) and President, The Coteau Properties Company (an NACoal subsidiary) (from September 2011)
 
From October 2013 to July 2014, President, The Coteau Properties Company (an NACoal subsidiary) and Director - Northern Operations of NACoal. From September 2011 to October 2013, President, The Coteau Properties Company. From prior to 2011 to September 2011, President, The Falkirk Mining Company (an NACoal subsidiary).

 
 
 
 
 
 
 
Michael J. Gregory
 
68

 
Vice President - Marketing and Special Projects of NACoal (from October 2013)
 
From prior to 2011 to September 2013, Vice President - International Operations and Special Projects of NACoal.
 
 
 
 
 
 
 
K. Donald Grischow
 
68

 
Treasurer, Director - Compensation and Benefits and Global Risk Management of NACoal (from January 2013)
 
From prior to 2011 to December 2012, Treasurer of NACoal
 
 
 
 
 
 
 
John R. Pokorny
 
60

 
Controller of NACoal (from prior to 2011)
 
 
 
 
 
 
 
 
 
J. Patrick Sullivan, Jr.


 
57

 
Vice President and Chief Financial Officer of NACoal (from May 2013)
 
From prior to 2011 to May 2013, Controller, Luminant Generation, Mining, Construction and Development of Energy-Future Holdings Corporation.
 
 
 
 
 
 
 
Harry B. Tipton, III
 
58

 
Vice President - Engineering, and Alabama, Louisiana and Mississippi Operations of NACoal (from July 2015)

 
From July 2014 to June 2015, Vice President - Engineering, and Alabama and Louisiana Operations of NACoal. From October 2013 to June 2014, Vice President - Engineering, and Alabama, Louisiana and Mississippi Operations of NACoal. From prior to 2011 to October 2013, Vice President - Engineering, and Louisiana and Mississippi Operations of NACoal.

30


PRINCIPAL OFFICERS OF THE COMPANY’S SUBSIDIARIES
B. HBB
Name
 
Age
 
Current Position
 
Other Positions
 
 
 
 
 
 
 
Gregory H. Trepp
 
54

 
President and Chief Executive Officer of HBB (from prior to 2011), Chief Executive Officer of KC (from prior to 2011)
 
From November 2013 to December 2014, Interim President of KC.
 
 
 
 
 
 
 
Keith B. Burns
 
59

 
Vice President, Engineering and Information Technology of HBB (from prior to 2011)
 
 
 
 
 
 
 
 
 
D. Scott Butler
 
64

 
Corporate Controller (from prior to 2011)
 
 
 
 
 
 
 
 
 
Richard E. Moss
 
52

 
Senior Director, Finance &Treasurer of HBB (from January 2011)
 
 
 
 
 
 
 
 
 
Gregory E. Salyers
 
55

 
Senior Vice President, Global Operations of HBB (from prior to 2011)
 
 
 
 
 
 
 
 
 
Dana B. Sykes
 
54

 
Vice President, General Counsel and Secretary of HBB (from September 2015)

 
From July 2014 to September 2015, Associate General Counsel, Assistant Secretary and Senior Director, Human Resources of HBB. From February 2012 to July 2014, Assistant General Counsel and Director, Human Resources of HBB. From prior to 2011 to February 2012, Assistant General Counsel of HBB.
 
 
 
 
 
 
 
James H. Taylor
 
58

 
Vice President and Chief Financial Officer of HBB (from January 2011)
 
 
 
 
 
 
 
 
 
R. Scott Tidey
 
51

 
Senior Vice President, North America Sales and Marketing of HBB (from prior to 2011)
 
 
C. KC
Name
 
Age
 
Current Position
 
Other Positions
Robert O. Strenski
 
59
 
President of KC (from January 2015)
 
From February 2014 to December 2014, Vice President, General Merchandise Manager of KC. From June 2013 to January 2014, General Merchandise Manager of KC. From prior to 2011 to January 2013, Vice President, Divisional Merchandise Manager, Consumables, Biglots Stores, Inc.



31


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.
The high and low sales prices for the Class A common stock and dividends per share for both classes of common stock for each quarter during the past two years are presented in the tables below:
 
2015
 
Sales Price
 
 
 
High
 
Low
 
Cash Dividend
Fourth quarter
$
50.85

 
$
40.04

 
$
0.2625

Third quarter
$
61.70

 
$
47.26

 
$
0.2625

Second quarter
$
62.96

 
$
48.04

 
$
0.2625

First quarter
$
60.99

 
$
48.42

 
$
0.2575

 
2014
 
Sales Price
 
 
 
High
 
Low
 
Cash Dividend
Fourth quarter 
$
63.88

 
$
47.42

 
$
0.2575

Third quarter
$
55.90

 
$
46.59

 
$
0.2575

Second quarter
$
56.86

 
$
46.50

 
$
0.2575

First quarter
$
62.84

 
$
49.44

 
$
0.2500

At December 31, 2015, there were 742 Class A common stockholders of record and 164 Class B common stockholders of record. See Note 19 to Consolidated Financial Statements contained elsewhere in this Form 10-K for a discussion of the amount of NACCO's investment in subsidiaries that was restricted at December 31, 2015.
Sales of Unregistered Company Stock
Pursuant to the Non-Employee Directors’ Equity Compensation Plan, the Company issued an aggregate of 10,584 shares of its Class A common stock on January 1, 2015, April 1, 2015, July 1, 2015 and October 1, 2015 for payment of a portion of the directors’ annual retainer fee. In addition, pursuant to the terms of the plan, 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, meeting attendance fees and any committee chairman's fees. An aggregate of 2,349 shares of Class A common stock was issued under voluntary elections on January 1, 2015, April 1, 2015, July 1, 2015 and October 1, 2015.
Pursuant to the Non-Employee Directors’ Equity Compensation Plan, the Company issued an aggregate of 10,318 shares of its Class A common stock on January 1, 2014, April 1, 2014, July 1, 2014 and October 1, 2014 for payment of a portion of the directors’ annual retainer fee. An aggregate of 1,091 shares of Class A common stock was issued under voluntary elections on January 1, 2014, April 1, 2014, July 1, 2014 and October 1, 2014.
Pursuant to the Non-Employee Directors’ Equity Compensation Plan, the Company issued an aggregate of 9,712 shares of its Class A common stock on January 1, 2013, April 1, 2013, July 1, 2013 and October 1, 2013 for payment of a portion of the directors’ annual retainer fee.An aggregate of 1,333 shares of Class A common stock was issued under voluntary elections on January 1, 2013, April 1, 2013, July 1, 2013 and October 1, 2013.
The issuances of these unregistered shares qualify as exempt transactions pursuant to Section 4(a)(2) of the Securities Act of 1933.

32



Purchases of Equity Securities by the Issuer and Affiliated Purchasers
Issuer Purchases of Equity Securities
Period
(a)
Total Number of Shares Purchased
 
(b)
Average Price Paid per Share
 
(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)
Month #1
(October 1 to 31, 2015)
15,944

 
$
47.75

 
15,944

 
$

Month #2
(November 1 to 30, 2015)

 
$

 

 
$

Month #3
(December 1 to 31, 2015)

 
$

 

 
$

     Total
15,944

 
$
47.75

 
15,944

 
$


(1)
In November 2013, NACCO announced a $60 million stock repurchase program. As of October 6, 2015, the Company completed the stock repurchase program with total repurchases of approximately 1,122,900 shares of Class A common stock.




33


Item 6. SELECTED FINANCIAL DATA
 
Year Ended December 31
 
2015
 
2014 (1)
 
2013
 
2012 (2)
 
2011(3)
 
(In thousands, except per share data)
Operating Statement Data:
 
 
 
 
 
 
 
 
 
Revenues
$
915,860

 
$
896,782

 
$
932,666

 
$
873,364

 
$
790,455

 
 
 
 
 
 
 
 
 
 
Operating profit (loss)
$
31,827

 
$
(66,309
)
 
$
61,336

 
$
67,642

 
$
64,074

 
 
 
 
 
 
 
 
 
 
Income (loss) from continuing operations
$
21,984

 
$
(38,118
)
 
$
44,450

 
$
42,163

 
$
79,470

Discontinued operations, net of tax(2)

 

 

 
66,535

 
82,601

Net income (loss)
$
21,984

 
$
(38,118
)
 
$
44,450

 
$
108,698

 
$
162,071

 
 
 
 
 
 
 
 
 
 
Basic earnings (loss) per share:
 
 
 
 
 
 
 
 
 
Continuing operations
$
3.14

 
$
(5.02
)
 
$
5.48

 
$
5.04

 
$
9.49

Discontinued operations(2)

 

 

 
7.93

 
9.85

Basic earnings (loss) per share
$
3.14

 
$
(5.02
)
 
$
5.48

 
$
12.97

 
$
19.34

 
 
 
 
 
 
 
 
 
 
Diluted earnings (loss) per share:
 
 
 
 
 
 
 
 
 
Continuing operations
$
3.13

 
$
(5.02
)
 
$
5.47

 
$
5.02

 
$
9.46

Discontinued operations(2)

 

 

 
7.90

 
9.82

Diluted earnings (loss) per share
$
3.13

 
$
(5.02
)
 
$
5.47

 
$
12.92

 
$
19.28


(1)
During the fourth quarter of 2014, NACoal determined that indicators of impairment existed at its Centennial mining operations and as a result reviewed the Centennial long-lived assets for impairment. NACoal recorded a non-cash, asset impairment charge of $105.1 million for Centennial's long-lived asset group. See Note 10 to the Consolidated Financial Statements for further discussion of the Company's long-lived asset impairment.
(2)
During 2012, NACCO spun-off Hyster-Yale Materials Handling, Inc. ("Hyster-Yale"), a former subsidiary. The results of operations of Hyster-Yale are reflected as discontinued operations in the table above.
(3)
In 2006, the Company initiated litigation in the Delaware Chancery Court against Applica Incorporated ("Applica") and individuals and entities affiliated with Applica's shareholder, Harbinger Capital Partners Master Fund, Ltd. The litigation alleged a number of contract and tort claims against the defendants related to the Company's failed transaction with Applica, which had been previously announced. On February 14, 2011, the parties to this litigation entered into a settlement agreement. The settlement agreement provided for, among other things, the payment of
$60 million to the Company and dismissal of the lawsuit with prejudice. The payment was received in February 2011. Litigation costs related to this matter were $2.8 million in 2011.

 


34


 
Year Ended December 31
 
2015
 
2014
 
2013
 
2012 (1)
 
2011
 
(In thousands, except per share and employee data)
Balance Sheet Data at December 31:
 
 
 
 
 
 
 
 
 
Total assets (1)
$
655,408

 
$
770,520

 
$
809,956

 
$
776,306

 
$
1,808,834

Long-term debt (1)
$
160,113

 
$
191,431

 
$
152,431

 
$
135,448

 
$
74,471

Stockholders' equity
$
201,138

 
$
211,474

 
$
297,780

 
$
281,331

 
$
576,210

 
 
 
 
 
 
 
 
 
 
Cash Flow Data:
 
 
 
 
 
 
 
 
 
Provided by operating activities (2)
$
108,002

 
$
19,799

 
$
53,065

 
$
143,014

 
$
155,179

Used for investing activities (2)
$
(8,291
)
 
$
(74,934
)
 
$
(60,734
)
 
$
(74,237
)
 
$
(32,701
)
Provided by (used for) financing activities (2)
$
(108,301
)
 
$
20,979

 
$
(36,776
)
 
$
(123,433
)
 
$
(41,871
)
 
 
 
 
 
 
 
 
 
 
Other Data:
 
 
 
 
 
 
 
 
 
Per share data:
 
 
 
 
 
 
 
 
 
Cash dividends (3)
$
1.0450

 
$
1.0225

 
$
1.0000

 
$
5.3775

 
$
2.1200

Market value at December 31
$
42.20

 
$
59.36

 
$
62.19

 
$
60.69

 
$
89.22

Stockholders' equity at December 31
$
29.42

 
$
29.23

 
$
37.83

 
$
33.68

 
$
68.81

 
 
 
 
 
 
 
 
 
 
Actual shares outstanding at December 31
6.837

 
7.236

 
7.872

 
8.353

 
8.374

Basic weighted average shares outstanding
7.001

 
7.590

 
8.105

 
8.384

 
8.383

Diluted weighted average shares outstanding
7.022

 
7.590

 
8.124

 
8.414

 
8.408

Total employees at December 31(4)
3,600

 
4,000

 
4,100

 
4,300

 
4,000


(1)
During 2012, the Company spun-off Hyster-Yale, a former subsidiary.
(2)
Includes both continuing operations and discontinued operations for 2012 and 2011.
(3)
2012 cash dividends include a one-time special cash dividend of $3.50 per share. The 25 cent dividend paid in the fourth quarter of 2012 was the first regular quarterly dividend following the spin-off of Hyster-Yale.
(4)
Includes employees of Weston Brands in 2014, Centennial from 2012 to 2014 and the unconsolidated mines for all years presented. Excludes employees of Hyster-Yale for all years presented.


35


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
NACCO Industries, Inc. (the parent company or “NACCO”) and its wholly owned subsidiaries (collectively, the “Company”) operate in the following principal industries: mining, small appliances and specialty retail. Results of operations and financial condition are discussed separately by subsidiary, which corresponds with the industry groupings.
The North American Coal Corporation and its affiliated coal companies (collectively, “NACoal”) mine coal primarily for use in power generation and provide selected value-added mining services for other natural resources companies. Hamilton Beach Brands, Inc. (“HBB”) is a leading designer, marketer and distributor of small electric household and specialty housewares appliances, as well as commercial products for restaurants, bars and hotels. The Kitchen Collection, LLC (“KC”), is a national specialty retailer of kitchenware in outlet and traditional malls throughout the U.S. 
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 generally recognized when title transfers and risk of loss passes to the customer. Under its mining contracts, the Company recognizes revenue as the coal or limerock is delivered or services are performed. Revenues at HBB are recognized when customer orders are completed and shipped. Revenues at KC are recognized at the point of sale when payment is made and customers take possession of the merchandise in stores. Reserves for discounts and returns are maintained for anticipated future claims at HBB and KC. The accounting policies used to develop these product discounts and returns include:
Product discounts: The Company records estimated reductions to revenues for customer programs and incentive offerings, including special pricing agreements, price competition, promotions and other volume-based incentives. At HBB, net sales represent gross sales less cooperative advertising, other volume-based incentives, estimated returns and allowances for defective products. At KC, retail markdowns are incorporated into KC's retail method of accounting for cost of sales. If market conditions were to decline or if competition were to increase, the Company may take actions to increase customer incentive offerings, possibly resulting in an incremental reduction of revenues at the time the incentive is offered. If the Company's estimates of customer programs and incentives were one percent higher than the levels offered during 2015, the reserves for product discounts would increase and revenues would be reduced by $0.1 million. The Company's past results of operations have not been materially affected by a change in the estimate of product discounts and although there can be no assurances, the Company is not aware of any circumstances that would be reasonably likely to materially change its estimates in the future.
Product returns: Products generally are not sold with the right of return. However, based on the Company's historical experience, a portion of products sold are estimated to be returned due to reasons such as buyer remorse, duplicate gifts received, product failure and excess inventory stocked by the customer which, subject to certain terms and conditions, the Company will agree to accept. The Company records estimated reductions to revenues at the time of sale based on this historical experience and the limited right of return provided to certain customers. If future trends were to change significantly from those experienced in the past, incremental reductions to revenues may result based on this new experience. If the Company's estimate of average return rates for each type of product sold were to increase by one percent over historical levels, the reserves for product returns would increase and revenues would be reduced by $0.2 million. The Company's past results of operations have not been materially affected by a change in the estimate of product returns and although there can be no assurances, the Company is not aware of any circumstances that would be reasonably likely to materially change its estimates in the future.

36


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)

Retirement benefit plans: The Company maintains various defined benefit pension plans that provide benefits based on years of service and average compensation during certain periods. During 2013, the Company amended the Combined Plan to freeze pension benefits for all employees, including those for certain unconsolidated mines' employees and cost of living adjustments for other employees, effective as of the close of business on December 31, 2013. All other eligible employees of the Company, including employees whose pension benefits are frozen, receive retirement benefits under defined contribution retirement plans. The Company's policy is to periodically make contributions to fund the defined benefit pension plans within the range allowed by applicable regulations. The defined benefit pension plan assets consist primarily of publicly traded stocks and government and corporate bonds. There is no guarantee the actual return on the plans’ assets will equal the expected long-term rate of return on plan assets or that the plans will not incur investment losses.
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 U.S. 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. Expected returns for pension plans are based on fair market value for non-U.S. pension plan assets.
The Company also maintains health care plans which provide benefits to eligible retired employees. All health care plans of the Company have a cap on the Company's share of the costs. These plans have no assets. Under the Company's current policy, plan benefits are funded at the time they are due to participants.
The basis for the selection of the discount rate for each plan is determined by matching the timing of the payment of the expected obligations under the defined benefit plans and health care plans against the corresponding yield of high-quality corporate bonds of equivalent maturities.
Changes to the estimate of any of these factors could result in a material change to the Company's pension obligation causing a related increase or decrease in reported net operating results in the period of change in the estimate. Because the 2015 assumptions are used to calculate 2016 pension expense amounts, a one percentage-point change in the expected long-term rate of return on plan assets would result in a change in pension expense for 2016 of approximately $0.6 million for the plans. A one percentage-point change in the discount rate would result in a change in pension expense for 2016 by approximately $0.1 million. A one percentage-point increase in the discount rate would have lowered the plans’ projected benefit obligation as of the end of 2015 by approximately $6.2 million; while a one percentage-point decrease in the discount rate would have raised the plans’ projected benefit obligation as of the end of 2015 by approximately $7.4 million.

See Note 16 to the Consolidated Financial Statements in this Form 10-K for further discussion of the Company's retirement benefit plans.
Self-insurance liabilities: The Company is generally self-insured for product liability, environmental liability, medical claims, certain workers’ compensation claims and certain closed mine liabilities. For product liability, catastrophic insurance coverage is retained for potentially significant individual claims. 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. Changes in any of these factors could materially change the Company's estimates for these self-insurance obligations causing a related increase or decrease in reported net operating results in the period of change in the estimate.
Accounting for Asset Retirement Obligations: The Company's asset retirement obligations are principally for costs to dismantle certain mining equipment at the end of the life of the mine as well as for costs to close its surface mines and reclaim the land it has disturbed as a result of its normal mining activities. 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

37


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)

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 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 Company determined the amounts of these obligations based on 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.
Inventory reserves: The Company writes down its inventory to the lower of cost or market, which includes an estimate for obsolescence or excess inventory based upon assumptions about future demand and market conditions. If actual market conditions are less favorable than those projected by management, additional inventory write-downs may be required. Upon a subsequent sale or disposal of the impaired inventory, the corresponding reserve for impaired value is relieved to ensure that the cost basis of the inventory reflects any write-downs. An impairment in value of one percent of net inventories would result in additional expense of approximately $1.7 million.
Allowances for doubtful accounts: The Company maintains allowances for doubtful accounts for estimated losses resulting from the failure of its customers to make required payments. These allowances are based on both recent trends of certain customers estimated to be a greater credit risk as well as general trends of the entire customer pool. If the financial condition of the Company's customers were to deteriorate, resulting in an impairment of their ability to make payments, additional allowances may be required. An impairment in value of one percent of net accounts receivable would require an increase in the allowance for doubtful accounts and would result in additional expense of approximately $1.1 million.
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 determined that indicators of potential impairment were present during the fourth quarter of 2014 with respect to its Centennial mining operations asset group. As a result, the Company assessed the recoverability of Centennial assets and determined that the assets were not fully recoverable when compared to the remaining future undiscounted cash flows from these assets. The Company estimated the fair value of the asset group and the long-lived assets were written down to their estimated fair value which resulted in a non-cash asset impairment charge of $105.1 million. The asset impairment charge was recorded as Centennial long-lived asset impairment charge in the Consolidated Statement of Operations for the year ended December 31, 2014 and relates exclusively to the NACoal segment. The fair value of the asset group was calculated using the combination of a market and income approach.
The fair value estimate for the coal land and real estate and other property, plant and equipment was calculated using market data for similar assets, which are classified as Level 2 inputs. The fair value of the coal supply agreement and non-compete intangible assets were estimated to be zero given current market conditions. Key inputs in this model are based on significant unobservable inputs and include the forecast of tons sold and coal pricing and are classified as Level 3 inputs.
In 2014 and 2013, KC considered its operating loss to be an indicator of impairment.  For KC’s asset impairment analysis, the primary input is projected future cash flows utilizing assumptions consistent with those the Company uses in its internal

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)

planning, which are classified as Level 3 inputs. As a result of the fiscal year-end review of long-lived store-related assets, the Company recorded impairment charges of $0.9 million and $1.1 million in 2014 and 2013, respectively, included in depreciation expense within Selling, general and administrative expenses in the Consolidated Statements of Operations. Long-lived assets at the stores consist mainly of leasehold improvements and furniture and fixtures. The fair value for leasehold improvements was determined to be zero as such assets were deemed to have no future use or economic benefit based on the Company's analysis using market participant assumptions, and therefore no expected future cash flows. The fair value for store fixtures is based on the market exit price based on historical experience. The impairment charges in 2014 were largely the result of decreased expected future operating results. If operating results do not improve, KC may be required to record additional long-lived asset impairment charges.
See Note 10 to the Consolidated Financial Statements in this Form 10-K for further discussion of the Company's long-lived asset impairments.
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. 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 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. 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.
Valuation of acquisitions: The allocation of the purchase price to the tangible assets and liabilities and identifiable intangible assets acquired requires management to make significant estimates in determining the fair values of assets acquired and liabilities assumed. These estimates can include, but are not limited to, the cash flows that the acquisition is expected to generate in the future and the appropriate weighted-average cost of capital. These estimates are inherently uncertain and unpredictable, and if different estimates were used, the purchase price for the acquisition may have been allocated to the acquired assets and liabilities assumed differently from the current allocation. Although the Company believes the assumptions, judgments and estimates used are reasonable and appropriate, different assumptions, judgments and estimates could materially affect the value ascribed to an acquired asset and the Company's results of operations and financial position if impairment charges were required to be recorded. See Note 22 to the Consolidated Financial Statements in this Form 10-K for further discussion of the Company's acquisitions.

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)

CONSOLIDATED FINANCIAL SUMMARY
Selected consolidated results of the Company and components of change by subsidiary were as follows:
 
Revenues
 
Operating profit (loss)
 
Net income (loss)
2013 Consolidated results
$
932,666

 
$
61,336

 
$
44,450

Increase (decrease) in 2014
 
 
 
 
 
NACoal (1)
(20,949
)
 
(126,491
)
 
(82,903
)
HBB
11,893

 
(5,188
)
 
(1,949
)
KC (net of eliminations)
(26,828
)
 
3,257

 
1,910

NACCO and Other

 
777

 
374

2014 Consolidated results
$
896,782

 
$
(66,309
)
 
$
(38,118
)
Increase (decrease) in 2015
 
 
 
 
 
NACoal
(24,704
)
 
89,551

 
56,596

HBB
61,294

 
(971
)
 
(3,395
)
KC (net of eliminations)
(17,512
)
 
8,348

 
4,903

NACCO and Other

 
1,208

 
1,998

2015 Consolidated results
$
915,860

 
$
31,827

 
$
21,984

 
2015
 
2014 (1)
 
2013
Consolidated results:
 
 
 
 
 
Basic earnings (loss) per share:
$
3.14

 
$
(5.02
)
 
$
5.48

Diluted earnings (loss) per share:
$
3.13

 
$
(5.02
)
 
$
5.47


(1)
During the fourth quarter of 2014, the Company recorded a non-cash asset impairment charge of $105.1 million. The asset impairment charge was recorded as Centennial long-lived asset impairment charge in the Consolidated Statement of Operations for the year ended December 31, 2014 and relates exclusively to the NACoal segment.






















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)

CONSOLIDATED INCOME TAXES

The Company’s income tax provision includes U.S. federal, state and local, and foreign income taxes. In determining the effective income tax rate, the Company analyzes various factors, including the Company’s annual earnings, taxing jurisdictions in which the earnings will be generated, the impact of state and local income taxes, the Company’s ability to use tax credits and net operating loss carryforwards, and available tax planning alternatives. Discrete items, including the effect of changes in tax laws, tax rates, certain circumstances with respect to valuation allowances or other unusual or non-recurring tax adjustments are reflected in the period in which they occur as an addition to, or reduction from, the income tax provision, rather than included in the effective income tax rate.
A reconciliation of the Company's consolidated federal statutory and effective income tax is as follows for the years ended December 31:
 
2015
 
2014
 
2013
Income (loss) before income tax provision (benefit)
$
24,799

 
$
(76,573
)
 
$
55,720

Statutory taxes (benefit) at 35.0%
$
8,679

 
$
(26,801
)
 
$
19,502

Discrete items:
 
 
 
 
 
Valuation allowances
3,557

 
5,742

 

NACoal reserves (settlements)
551

 
(1,360
)
 

HBB reserves (settlements)
414

 
(1,533
)
 

NACCO and other settlements

 

 
116

Tax law changes
18

 

 
(503
)
Provision to return adjustments
(535
)
 
(867
)
 
(330
)
Other, net
24

 
(414
)
 
(721
)
 
4,029

 
1,568

 
(1,438
)
Permanent items:
 
 
 
 
 
Percentage depletion
(8,199
)
 
(7,091
)
 
(8,008
)
State income taxes
(1,334
)
 
(6,361
)
 
1,106

Federal credits
(1,196
)
 
(529
)
 
(941
)
Non-deductible expenses
787