Market Overview

Cloud Peak Energy Inc. Announces Results for Second Quarter and First Six Months of 2018

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Cloud Peak Energy Inc. (NYSE:CLD), one of the largest U.S. coal
producers and the only pure-play Powder River Basin ("PRB") coal
company, today announced results for the second quarter and first six
months of 2018.

Colin Marshall, President and Chief Executive Officer, commented, "The
second quarter was challenging as shipments were behind plan primarily
due to weather and operational issues at our Antelope Mine. We are
working to make up as many of the delayed shipments as we can through
the second half of the year. While domestic coal burn is up, and utility
coal stockpiles are decreasing, buying is currently slow and prices
remain subdued. Our export business remained strong allowing us to
export 1.3 million tons during the quarter. We continue to expect to
export approximately 5.5 million tons in 2018. We are pleased to have
amended and extended our existing Westshore throughput agreement, which
increases annual capacity to 10.5 million tons in 2021 and 2022."

Highlights

  • Amended and extended the existing Westshore throughput agreement to
    increase annual capacity from 5.5 million tons to 10.5 million tons in
    2021 and 2022. Cloud Peak Energy retained the right to terminate the
    agreement at any time in exchange for a buyout payment.
  • Amended the Credit Agreement to extend its maturity to May 24, 2021
    while reducing the maximum borrowing capacity from $400 million to
    $150 million. Ended the quarter with $90.2 million of cash and cash
    equivalents and total available liquidity of $171.2 million, including
    availability under the Credit Agreement.
  • Exercised a coal lease option with the Crow Tribe of Indians,
    providing approximately 290 million in-place tons(1) and
    extended the lease options on two additional project areas totaling
    approximately 1.1 billion in-place tons(1). Paid
    approximately $1.8 million to the Crow Tribe in connection with
    exercising the option and option extensions.
 

(1)

 

Represents a current estimate of physical in-place coal tons.
Does not represent proven and probable reserves, non-reserve coal
deposits or a forecast of tons to be produced and sold in the
future. Future production and sales of such tons, if any, are
subject to exercise of remaining options, regulatory approvals,
completion of land access agreements, and significant risk and
uncertainty, including coal demand and pricing in the U.S. and
internationally.

 
 

Second Quarter Results

 
    Quarter Ended     Year to Date
(in millions, except per ton amounts)     06/30/18     06/30/17     06/30/18     06/30/17
Consolidated            
Net income (loss) $ (29.9 ) $ (6.9 ) $ (37.6 ) $ (27.1 )
Adjusted EBITDA (1) $ (0.8 ) $ 29.6 $ 18.9 $ 50.0
 
Owned and Operated Mines Segment
Shipments - owned and operated mines (tons) 11.6 14.3 23.8 28.4
 
Realized price per ton sold $ 12.18 $ 12.25 $ 12.19 $ 12.18
Average cost per ton sold $ 11.90 $ 9.81 $ 11.41 $ 9.84
Cash margin per ton sold (2) $ 0.28 $ 2.44 $ 0.78 $ 2.34
 
Segment operating income (loss) $ (12.2 ) $ 14.0 $ (11.0 ) $ 24.6
Segment Adjusted EBITDA (1) $ 5.3 $ 36.7 $ 23.9 $ 70.5
 
Logistics and Related Activities Segment
Shipments - Asian exports (tons) 1.3 1.3 2.7 1.8
 
Realized price per ton sold - Asian exports $ 59.78 $ 49.06 $ 58.41 $ 49.19
Average cost per ton sold - Asian exports $ 54.32 $ 47.93 $ 53.17 $ 50.08
Cash margin per ton sold - Asian exports (2) $ 5.46 $ 1.13 $ 5.24 $ (0.89 )
 
Segment operating income (loss) $ 5.6 $ (3.4 ) $ 11.0 $ (10.9 )
Segment Adjusted EBITDA (1) $ 7.3 $ 1.6 $ 14.4 $ (0.9 )
 
Selling, general and administrative expenses     $ 13.0       $ 9.8       $ 20.3       $ 20.8  

(1) Non-GAAP financial measure; see definition and
reconciliation in this release and the attached tables.

(2) Calculated by subtracting the average cost per ton sold
from the realized price per ton sold.

 
  • Shipments of 11.6 million tons during the second quarter of 2018
    compared to 14.3 million tons for the second quarter of 2017.
  • Exported 1.3 million tons during the second quarter and have
    contracted 4.1 million tons for 2018 delivery at prices higher than
    those realized in 2017.
  • Net loss was $29.9 million for the second quarter of 2018 compared
    with a $6.9 million net loss during the second quarter of 2017, which
    was primarily driven by the lower domestic shipments during the second
    quarter of 2018.
  • Adjusted EBITDA of $(0.8) million during the second quarter of 2018
    compared to $29.6 million for the second quarter of 2017.

Health, Safety, and Environment

During the second quarter of 2018, among the Company's approximately
1,100 full-time, mine site employees, there were no reportable injuries.
The year-to-date Mine Safety and Health Administration ("MSHA") All
Injury Frequency Rate ("AIFR") is zero compared to a rate of 0.17
through the second quarter of 2017. During the quarter there were 57
MSHA inspector days at the mine sites. The Company was issued no
significant and substantial citations during the quarter.

There were no reportable environmental incidents during the quarter.

Operating Results

Owned and Operated Mines

The Owned and Operated Mines segment comprises the results of mine site
sales from the Company's three mines primarily to its domestic utility
customers and to the Logistics and Related Activities segment.

 
    Quarter Ended     Year to Date
(in millions, except per ton amounts)     06/30/18     06/30/17     06/30/18     06/30/17
Tons sold 11.6     14.3     23.8     28.4
Revenue $ 143.9 $ 178.7 $ 297.5 $ 352.2
Cost of product sold $ 139.6 $ 142.1 $ 275.6 $ 282.6
Realized price per ton sold $ 12.18 $ 12.25 $ 12.19 $ 12.18
Average cost per ton $ 11.90 $ 9.81 $ 11.41 $ 9.84
Cash margin per ton sold (1) $ 0.28 $ 2.44 $ 0.78 $ 2.34
Segment operating income (loss) $ (12.2 ) $ 14.0 $ (11.0 ) $ 24.6
Segment Adjusted EBITDA (2)     $ 5.3       $ 36.7     $ 23.9       $ 70.5

(1) Calculated by subtracting the average cost per ton sold
from the realized price per ton sold.

(2) Non-GAAP financial measure; see definition and
reconciliation in this release and the attached tables.

 

Shipments during the second quarter of 2018 were 19 percent lower than
the second quarter of 2017, primarily due to lower shipments at the
Antelope Mine. Antelope production was impacted by several rain
interruptions, a delay in moving a dragline to a low strip ratio pit due
to nesting golden eagles, a dragline down for a planned tub replacement
and below plan truck productivity. Strip ratios have increased more in
2018 than in recent years resulting in higher cost per ton. Cordero Rojo
tons were also reduced due to continued low demand for 8400 Btu coal.

Revenue from the Owned and Operated Mines segment decreased 19 percent
in the second quarter of 2018 compared to the second quarter of 2017 due
to the lower shipments as well as $0.07 per ton lower average realized
prices. Cost per ton was $11.90 for the second quarter of 2018 compared
with $9.81 for the second quarter of 2017. The 21 percent higher cost
per ton in 2018 was primarily driven by lower production rates,
previously disclosed increased strip ratios, and higher per ton fuel and
lube costs due to an increase in the price of diesel.

Logistics and Related Activities

The Logistics and Related Activities segment comprises the results of
the Company's logistics and transportation services to its domestic and
international export customers including the incremental production
taxes and royalties associated with these sales.

 
    Quarter Ended     Year to Date
(in millions, except per ton amounts)     06/30/18     06/30/17     06/30/18     06/30/17
Total tons delivered 1.3     1.3     2.7     1.9
Asian exports (tons) 1.3 1.3 2.7 1.8
Domestic (tons)(1) 0.1 0.1
Revenue $ 79.3 $ 66.0 $ 159.0 $ 94.2
Total cost of product sold $ 73.7 $ 69.4 $ 148.0 $ 105.1
 
Asian Exports (per ton sold)
Realized price $ 59.78 $ 49.06 $ 58.41 $ 49.19
Average cost $ 54.32 $ 47.93 $ 53.17 $ 50.08
Cash margin (2) $ 5.46 $ 1.13 $ 5.24 $ (0.89 )
 
Domestic (per ton sold)
Realized price $ 55.00 $ 50.74 $ 45.48 $ 48.04
Average cost $ 48.96 $ 50.13 $ 40.06 $ 45.32
Cash margin (2) $ 6.04 $ 0.61 $ 5.42 $ 2.72
 
Segment operating income (loss) $ 5.6 $ (3.4 ) $ 11.0 $ (10.9 )
Segment Adjusted EBITDA (3)     $ 7.3     $ 1.6       $ 14.4     $ (0.9 )

Note: Due to the tabular presentation of rounded amounts,
certain numbers reflect insignificant rounding differences.

(1) For the three months ended June 30, 2018 and 2017, the
domestic logistics volumes were 45,400 tons and 40,400 tons,
respectively.

(2) Calculated by subtracting the average cost per ton sold
from the realized price per ton sold.

(3) Non-GAAP financial measure; see definition and
reconciliation in this release and the attached tables.

 

Strong Asian utility demand and favorable pricing allowed the Company to
export 1.3 million tons during the second quarter of 2018. Second
quarter 2018 segment operating income was $5.6 million, as compared to a
loss of $3.4 million for the second quarter of 2017. Segment operating
income (loss) includes amortization of logistics contract amendment
payments settled in previous years. With the previously disclosed
logistics contract extension for the Westshore agreement, this non-cash
amortization will reduce but continue to the end of the extended
agreement with Westshore in December 2022. Higher prices, partially
offset by rail fuel surcharges, higher severance taxes, and price
variable rail rates, resulted in second quarter Segment Adjusted EBITDA
increasing from $1.6 million in 2017 to $7.3 million this year.

The higher expected export volumes and pricing in 2018 are anticipated
to partially offset the lower expected contribution from the Owned and
Operated mines.

Cash, Liquidity, and Financial Position

Cash and cash equivalents as of June 30, 2018 were $90.2 million. Cash
provided by operations totaled $3.6 million during the first half of the
year. Capital expenditures were $4.8 million for the first half of 2018,
of which $2.2 million occurred during the second quarter.

During the second quarter of 2018, the Company amended its Credit
Agreement to extend the maturity to May 24, 2021 while reducing the
maximum borrowing capacity from $400 million to $150 million. New
quarterly financial covenants were added as well. The borrowing capacity
is limited by the financial covenants, calculated on a quarterly basis,
and will fluctuate from quarter to quarter. As of June 30, 2018, the
Company had available borrowing capacity of $81 million under the Credit
Agreement.

The Company also amended its A/R Securitization Program to extend the
term, which now matches the Credit Agreement maturity date. The A/R
Securitization Program allows for a maximum borrowing capacity of $70
million. The borrowing capacity is limited by eligible accounts
receivable (as defined under the terms of the A/R Securitization
Program), calculated on a monthly basis, and will fluctuate from month
to month.

The Company had $22.0 million in undrawn letters of credit under its A/R
Securitization Program as of June 30, 2018. These letters of credit are
currently being used to provide collateral for the Company's reclamation
bonds and have fully utilized the available capacity under the A/R
Securitization Program. As of June 30, 2018, the Company had $5.6
million of restricted cash related to the cash-collateralization
requirement of the A/R Securitization Program at May 31, 2018. The
available capacity under the A/R Securitization Program increased to
$20.5 million at the end of June 2018, which reduced the required
cash-collateralization to $1.5 million.

Including cash on hand and the availability under the Credit Agreement,
the Company ended the quarter with total available liquidity of $171.2
million.

Domestic Outlook

Mine shipments to domestic customers during the second quarter of 2018
were 10.2 million tons, as compared to 13.0 million tons shipped to
domestic customers in the second quarter of 2017. Shipments during the
second quarter of 2018 were negatively impacted by the previously
discussed operational issues at the Antelope Mine, as well as low demand
at the Cordero Rojo Mine. Cloud Peak Energy has worked with its
customers to move contracted volumes into the third quarter.

Natural gas prices during the second quarter remained in the range of
$2.75 to $3.00 per MMBtu. While storage volumes remain well below
average, natural gas prices have been steady due to increasing
production. As of July 6, 2018, U.S. Energy Information Administration
data showed that natural gas inventories have declined by 25 percent
compared to year ago levels.

Utility coal stockpile levels have decreased since year-end. Energy
Ventures Analysis estimates there were 62 million tons of PRB coal
inventories on utility stockpiles at the end of June 2018, a decline of
10 million tons from December 2017 levels. The Company believes customer
inventories will decline over the summer months as summer demand
increases, which could increase contracting later in the year.

For 2018, the Company plans to ship between 50 and 54 million tons with
current commitments to sell 49 million tons, which includes 4.1 million
tons contracted with export customers. All of the 49 million tons are
under fixed-price contracts with a weighted-average price of $12.27 per
ton. Full year results will be impacted by the Company's ability to sell
the additional tons and their pricing. The approximately 2.0 million
tons for 2018 that were priced during the second quarter of 2018
averaged $12.04 per ton, in line with prevailing prices at that time for
the qualities of coal contracted.

The Company is contracted to sell 29 million tons in 2019. Of this
committed production, 22 million tons are under fixed-price contracts
with a weighted-average price of $12.55 per ton. For 2019, there were
5.0 million tons contracted during the second quarter of 2018 averaging
$12.28 per ton.

Spring Creek Complex Development

On June 7, 2018, Big Metal Coal Co. LLC ("Big Metal"), a subsidiary of
Cloud Peak Energy, delivered notice to the Crow Tribe of Indians ("Crow
Tribe") to exercise the Upper Youngs Creek coal lease option and extend
the coal lease options for the Squirrel Creek and Tanner Creek project
areas. In connection with the option exercise and option extension, Big
Metal paid approximately $1.8 million to the Crow Tribe in June 2018.
The coal lease will require completion of land access agreements and
approval from the U.S. Department of the Interior. The coal located at
the Big Metal project is similar quality to that of the Spring Creek
Mine and offers lower sodium levels.

International Outlook

The international thermal Newcastle coal price index rebounded during
the second quarter to over $100 per tonne, currently settling around
$120 per tonne due to strong summer demand. During the same period, the
Kalimantan 5000 GAR index price, which the Spring Creek Mine coal
typically prices against, has remained under $70 per tonne. Based on
estimates through May 2018, thermal imports into China have increased 18
million tonnes, or almost 24 percent, compared to May 2017. China's
electricity generation has increased by 8.6 percent through May after
increasing by 6.5 percent last year, with most of this increase from
thermal coal generation.

Thermal coal imports to India have increased by nearly 10 percent this
year as domestic coal production has struggled to keep pace with rising
demand. South Korean thermal coal imports continue to grow as recently
commissioned plants increase their generation. Since the Company
announced the JERA Trading contract to supply a new IGCC power plant in
Japan from late 2019, the Company has been discussing test burns with
five Japanese utilities. Two test burns have been successfully completed
and discussions for four more test cargos are underway. There is no
assurance that these test burns will lead to future sales.

The Company exported 1.3 million tons during the second quarter of 2018.
The Company expects to realize higher prices during the second half of
2018 as selling prices have increased. The benefit of increased prices
will be tempered by increased port fees, rail fuel surcharges, price
variable rail costs and increased severance taxes due to higher prices.
With strong demand for Cloud Peak Energy coal, and the rail and port
system operating as expected, the Company expects export shipments of
approximately 5.5 million tons in 2018. The Company has contracted to
sell 4.1 million tons for delivery in 2018.

2018 Guidance – Financial and Operational Estimates

The following table provides the current outlook and assumptions for
selected 2018 consolidated financial and operational metrics:

             
          Estimate or Estimated Range
  Coal shipments for the three mines(1)     50 – 54 million tons
Committed sales with fixed prices Approximately 49 million tons
Anticipated realized price of produced coal with fixed prices Approximately $12.27 per ton
Adjusted EBITDA(2) $65 – $85 million
Net interest expense Approximately $37 million
Cash interest paid Approximately $42 million
Depreciation, depletion, amortization, and accretion $75 – $85 million
    Capital expenditures     $15 – $20 million

(1)

Inclusive of intersegment sales.

(2)

Non-GAAP financial measure; please see definition below in
this release. Management did not prepare estimates of
reconciliation with comparable GAAP measures, including net
income, because information necessary to provide such a
forward-looking estimate is not available without unreasonable
effort.

 

Conference Call Details

A conference call with management is scheduled at 5:00 p.m. ET on July
26, 2018 to review the results and current business conditions. The call
will be webcast live over the Internet from www.cloudpeakenergy.com
under "Investor Relations." Participants should follow the instructions
provided on the website for downloading and installing the audio
applications necessary to join the webcast. Interested individuals also
can access the live conference call via telephone at (855) 793-3260
(domestic) or (631) 485-4929 (international) and entering pass code
9790888.

Following the live webcast, a replay will be available at the same URL
on the website for seven days. A telephonic replay will also be
available approximately two hours after the call and can be accessed by
dialing (855) 859-2056 (domestic) or (404) 537-3406 (international) and
entering pass code 9790888. The telephonic replay will be available for
seven days.

About Cloud Peak Energy®

Cloud Peak Energy Inc. (NYSE:CLD) is headquartered in Wyoming and is one
of the largest U.S. coal producers and the only pure-play Powder River
Basin coal company. As one of the safest coal producers in the nation,
Cloud Peak Energy mines low sulfur, subbituminous coal and provides
logistics supply services. The Company owns and operates three surface
coal mines in the PRB, the lowest cost major coal producing region in
the nation. The Antelope and Cordero Rojo mines are located in Wyoming
and the Spring Creek Mine is located in Montana. In 2017, Cloud Peak
Energy sold approximately 58 million tons from its three mines to
customers located throughout the U.S. and around the world. Cloud Peak
Energy also owns rights to substantial undeveloped coal and
complementary surface assets in the Northern PRB, further building the
Company's long-term position to serve Asian export and domestic
customers. With approximately 1,300 total employees, the Company is
widely recognized for its exemplary performance in its safety and
environmental programs. Cloud Peak Energy is a sustainable fuel supplier
for approximately two percent of the nation's electricity.

Cautionary Note Regarding Forward-Looking Statements

This release and our related quarterly investor presentation contain
"forward-looking statements" within the meaning of the safe harbor
provisions of Section 27A of the Securities Act of 1933 and Section 21E
of the Securities Exchange Act of 1934. Forward-looking statements are
not statements of historical facts and often contain words such as
"anticipate," "believe," "could," "estimate," "expect," "intend," "may,"
"plan," "potential," "seek," "should," "will," "would," or words of
similar meaning. Forward-looking statements may include, for example:
(1) our outlook for 2018 and future periods for Cloud Peak Energy, the
Powder River Basin ("PRB") and the industry in general; (2) our
operational, financial and shipment guidance, including our ability in
the second half of the year to make up for decreased first half 2018
shipments, export shipments expected in 2018 and the anticipated timing,
volumes and benefits of our export supply agreement with JERA Trading;
(3) estimated thermal coal demand by domestic and Asian utilities; (4)
coal stockpile and natural gas storage levels and the impacts on future
demand and pricing; (5) our ability to sell additional tons in 2018 and
future periods at improved, economic prices; (6) the impact of the Trump
administration energy policies, ongoing state, local and international
anti-coal regulatory and political developments, NGO activities and
global climate change initiatives; (7) potential commercialization of
carbon capture technologies for utilities; (8) the impact of competition
from other domestic and international coal producers, natural gas
supplies and other alternative sources of energy used to generate
electricity; (9) the timing and extent of any sustained recovery for
depressed thermal coal industry conditions; (10) the impact of industry
conditions on our financial performance, liquidity and compliance with
the financial covenants in our Credit Agreement; (11) our ability to
manage our take-or-pay exposure for committed port and rail capacity;
(12) our future liquidity and access to sources of capital and credit to
support our existing operations and growth opportunities; (13) the
impact of any hedging programs; (14) our ability to renew or obtain
surety bonds to meet regulatory requirements; (15) our cost management
efforts; (16) operational plans for our mines; (17) business development
and growth initiatives; (18) our plans to acquire or develop additional
coal to maintain and extend our mine lives; (19) our estimates of the
quality and quantity of economic coal associated with our development
projects, the potential development of our Youngs Creek and other
Northern PRB assets, and our potential exercise of remaining options for
Crow Tribal coal; (20) potential development of additional export
terminal capacity and increased future access to existing or new
capacity; (21) industry estimates of the U.S. Energy Information
Administration and other third party sources; and (22) other statements
regarding our current plans, strategies, expectations, beliefs,
assumptions, estimates and prospects concerning our business, operating
results, financial condition, industry, economic conditions, government
regulations, energy policies and other matters that do not relate
strictly to historical facts.

These statements are subject to significant risks, uncertainties, and
assumptions that are difficult to predict and could cause actual results
to differ materially and adversely from those expressed or implied in
the forward-looking statements. The following factors are among those
that may cause actual results to differ materially and adversely from
our forward-looking statements: (1) the timing and extent of any
sustained recovery of the currently depressed coal industry and the
impact of ongoing or further depressed industry conditions on our
financial performance, liquidity, and financial covenant compliance; (2)
the prices we receive for our coal and logistics services, our ability
to effectively execute our forward sales strategy, and changes in
utility purchasing patterns resulting in decreased long-term purchases
of coal; (3) the timing of reductions or increases in customer coal
inventories; (4) our ability to obtain new coal sales agreements on
favorable terms, to resolve customer requests for reductions or
deferrals, and to respond to any cancellations of their committed
volumes on terms that preserve the amount and timing of our forecasted
economic value; (5) the impact of increasingly variable and less
predictable demand for thermal coal based on natural gas prices, summer
cooling demand, winter heating demand, economic growth rates and other
factors that impact overall demand for electricity; (6) our ability to
efficiently and safely conduct our mining operations and to adjust our
planned production levels to respond to market conditions and
effectively manage the costs of our operations; (7) competition with
other producers of coal and with traders and re-sellers of coal,
including the current oversupply of thermal coal, the impacts of
currency exchange rate fluctuations and the strong U.S. dollar, and
government environmental, energy and tax policies and regulations that
make foreign coal producers more competitive for international
transactions; (8) the impact of coal industry bankruptcies on our
competitive position relative to other companies who have emerged from
bankruptcy with reduced leverage and potentially reduced operating
costs; (9) competition with natural gas, wind, solar and other non-coal
energy resources, which may continue to increase as a result of low
domestic natural gas prices, the declining cost of renewables, and due
to environmental, energy and tax policies, regulations, subsidies and
other government actions that encourage or mandate use of alternative
energy sources; (10) coal-fired power plant capacity and utilization,
including the impact of climate change and other environmental
regulations and initiatives, energy policies, political pressures, NGO
activities, international treaties or agreements and other factors that
may cause domestic and international electric utilities to continue to
phase out or close existing coal-fired power plants, reduce or eliminate
construction of any new coal-fired power plants, or reduce consumption
of coal from the PRB; (11) the failure of economic, commercially
available carbon capture technology to be developed and adopted by
utilities in a timely manner; (12) the impact of "keep coal in the
ground" campaigns and other well-funded, anti-coal initiatives by
environmental activist groups and others targeting substantially all
aspects of our industry; (13) our ability to offset declining U.S.
demand for coal and achieve longer term growth in our business through
our logistics revenue and export sales, including the significant impact
of Chinese and Indian thermal coal import demand and production levels
from other countries and basins on overall seaborne coal prices, and the
impact of any "trade wars" on our export business; (14) railroad, export
terminal and other transportation performance, costs and availability,
including the availability of sufficient and reliable rail capacity to
transport PRB coal, the development of any future export terminal
capacity and our ability to access capacity on commercially reasonable
terms; (15) the impact of our rail and terminal take-or-pay commitments
if we do not meet our required export shipment obligations, including
our commitments entered as part of our export supply agreement with JERA
Trading; (16) weather conditions and weather-related damage that impact
our mining operations, our customers, or transportation infrastructure;
(17) operational, geological, equipment, permit, labor, and other risks
inherent in surface coal mining; (18) future development or operating
costs for our development projects exceeding our expectations or other
factors adversely impacting our development projects; (19) our ability
to successfully acquire coal and appropriate land access rights at
economic prices and in a timely manner and our ability to effectively
resolve issues with conflicting mineral development that may impact our
mine plans; (20) the impact of asset impairment charges if required as a
result of challenging industry conditions or other factors, including
any impairments associated with our development projects; (21) our plans
and objectives for future operations and the development of additional
coal reserves, including risks associated with acquisitions; (22) the
impact of current and future environmental, health, safety, endangered
species and other laws, regulations, treaties, executive orders, court
decisions or governmental policies, or changes in interpretations
thereof and third-party regulatory challenges, including additional
requirements, uncertainties, costs, liabilities or restrictions
adversely affecting the use, demand or price for coal, our mining
operations or the logistics, transportation, or terminal industries;
(23) the impact of required regulatory processes and approvals to lease
coal and obtain, maintain and renew permits for coal mining operations
or to transport coal to domestic and foreign customers, including
third-party legal challenges to regulatory approvals that are required
for some or all of our current or planned mining activities; (24) any
increases in rates or changes in regulatory interpretations or
assessment methodologies with respect to royalties or severance and
production taxes and the potential impact of associated interest and
penalties; (25) inaccurately estimating the costs or timing of our
reclamation and mine closure obligations and our assumptions underlying
reclamation and mine closure obligations; (26) our ability to obtain
required surety bonds and provide any associated collateral on
commercially reasonable terms; (27) the availability of, disruptions in
delivery or increases in pricing from third-party vendors of raw
materials, capital equipment and consumables which are necessary for our
operations, such as explosives, petroleum-based fuel, tires, steel, and
rubber; (28) our assumptions concerning coal reserve estimates; (29) our
relationships with, and other conditions affecting, our customers
(including our largest customers who account for a significant portion
of our total revenue) and other counterparties, including economic
conditions and the credit performance and credit risks associated with
our customers and other counterparties, such as traders, brokers, and
lenders under our Amended Credit Agreement and financial institutions
with whom we maintain accounts or enter hedging arrangements; (30) the
results of our hedging programs and changes in the fair value of
derivative financial instruments that are not accounted for as hedges;
(31) the terms and restrictions of our indebtedness; (32) liquidity
constraints, access to capital and credit markets and availability and
costs of credit, surety bonds, letters of credit, and insurance,
including risks resulting from the cost or unavailability of financing
due to debt and equity capital and credit market conditions for the coal
sector or in general, changes in our credit rating, our compliance with
the covenants in our debt agreements, credit pressures on our industry
due to depressed conditions, any demands for increased collateral by our
surety bond providers or the recent significant reduction in our
borrowing capacity under our Amended Credit Agreement; (33) volatility
in the price of our common stock, including the impact of any delisting
of our stock from the New York Stock Exchange if we fail to meet the
minimum average closing price listing standard; (34) our liquidity,
results of operations, and financial condition generally, including
amounts of working capital that are available; (35) litigation and other
contingencies; (36) the authority of federal and state regulatory
authorities to order any of our mines to be temporarily or permanently
closed under certain circumstances; (37) volatility in our results due
to quarterly mark-to-market accounting for certain historical equity
compensation awards; and (38) other risk factors or cautionary language
described from time to time in the reports and registration statements
we file with the Securities and Exchange Commission, including those in
Item 1A - Risk Factors in our most recent Form 10-K and any updates
thereto in our Forms 10-Q and current reports on Form 8-K.

Additional factors, events, or uncertainties that may emerge from time
to time, or those that we currently deem to be immaterial, could cause
our actual results to differ, and it is not possible for us to predict
all of them. We make forward-looking statements based on currently
available information, and we assume no obligation to, and expressly
disclaim any obligation to, update or revise publicly any
forward-looking statements made in this release or our related quarterly
investor presentation, whether as a result of new information, future
events or otherwise, except as required by law.

Non-GAAP Financial Measures

This release and our related presentation include the non-GAAP financial
measure of Adjusted EBITDA (on a consolidated basis and for our
reporting segments). Adjusted EBITDA is intended to provide additional
information only and does not have any standard meaning prescribed by
generally accepted accounting principles in the United States of America
("U.S. GAAP"). Quantitative reconciliations of historical net income
(loss) and segment operating income (loss) to Adjusted EBITDA are found
in the tables accompanying this release. EBITDA represents net income
(loss) before: (1) interest income (expense), net, (2) income tax
provision, (3) depreciation and depletion, and (4) amortization.
Adjusted EBITDA represents EBITDA as further adjusted for accretion,
which represents non-cash increases in asset retirement obligation
liabilities resulting from the passage of time, and specifically
identified items that management believes do not directly reflect our
core operations. For the periods presented herein, the specifically
identified items are: (1) adjustments to exclude non-cash impairment
charges, (2) adjustments for derivative financial instruments, excluding
fair value mark-to-market gains or losses and including cash amounts
received or paid, (3) adjustments to exclude debt restructuring costs,
and (4) non-cash throughput amortization expense and contract
termination payments made to amend the BNSF and Westshore agreements. We
enter into certain derivative financial instruments such as put options
that require the payment of premiums at contract inception. The
reduction in the premium value over time is reflected in the
mark-to-market gains or losses. Our calculation of Adjusted EBITDA does
not include premiums paid for derivative financial instruments; either
at contract inception, as these payments pertain to future settlement
periods, or in the period of contract settlement, as the payment
occurred in a preceding period. In prior years the amortization of port
and rail contract termination payments were included as part of EBITDA
and Adjusted EBITDA because the cash payments approximated the amount of
amortization being taken during the year. During 2017, management
determined that the non-cash portion of amortization arising from
payments made in prior years, as well as the amortization of contract
termination payments, should be adjusted out of Adjusted EBITDA because
the ongoing cash payments are now significantly smaller than the overall
amortization of these payments and no longer reflect the transactional
results. Because of the inherent uncertainty related to the items
identified above, management does not believe it is able to provide a
meaningful forecast of the comparable GAAP measures or reconciliation to
any forecasted GAAP measure.

Adjusted EBITDA is an additional tool intended to assist our management
in comparing our performance on a consistent basis for purposes of
business decision making by removing the impact of certain items that
management believes do not directly reflect our core operations.
Adjusted EBITDA is a metric intended to assist management in evaluating
operating performance, comparing performance across periods, planning
and forecasting future business operations and helping determine levels
of operating and capital investments. Period-to-period comparisons of
Adjusted EBITDA are intended to help our management identify and assess
additional trends potentially impacting our company that may not be
shown solely by period-to-period comparisons of net income (loss) or
segment operating income (loss). Consolidated Adjusted EBITDA is also
used as part of our incentive compensation program for our executive
officers and others.

We believe Adjusted EBITDA is also useful to investors, analysts, and
other external users of our Consolidated Financial Statements in
evaluating our operating performance from period to period and comparing
our performance to similar operating results of other relevant
companies. Adjusted EBITDA allows investors to measure a company's
operating performance without regard to items such as interest expense,
taxes, depreciation and depletion, amortization and accretion and other
specifically identified items that are not considered to directly
reflect our core operations.

Our management recognizes that using Adjusted EBITDA as a performance
measure has inherent limitations as compared to net income (loss),
segment operating income (loss), or other GAAP financial measures, as
this non-GAAP measure excludes certain items, including items that are
recurring in nature, which may be meaningful to investors. As a result
of these exclusions, Adjusted EBITDA should not be considered in
isolation and does not purport to be an alternative to net income
(loss), segment operating income (loss), or other GAAP financial
measures as a measure of our operating performance. Because not all
companies use identical calculations, our presentation of Adjusted
EBITDA may not be comparable to other similarly titled measures of other
companies.

 
CLOUD PEAK ENERGY INC.
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF
OPERATIONS AND COMPREHENSIVE INCOME (LOSS)
(in thousands, except per share data)
 
    Three Months Ended     Six Months Ended

 

June 30, June 30,
2018     2017 2018     2017
Revenue $ 205,698   $ 229,201   $ 422,007   $ 424,930  
Costs and expenses

Cost of product sold (exclusive of depreciation, depletion, and
accretion)

196,410 195,700 388,944 365,969
Depreciation and depletion 14,401 19,249 29,396 37,894
Accretion 1,706 1,846 3,411 3,667
(Gain) loss on derivative financial instruments 1,595 3,939
Selling, general and administrative expenses 12,975 9,827 20,292 20,801
Impairments 800 800
Other operating costs   55     92     183     310  
Total costs and expenses   226,347     228,309     443,026     432,580  
Operating income (loss)   (20,649 )   892     (21,019 )   (7,650 )
Other income (expense)

Net periodic postretirement benefit income (cost), excluding
service cost

1,617 1,592 3,235 3,182
Interest income 274 118 538 157
Interest expense (10,541 ) (9,866 ) (19,729 ) (22,778 )
Other, net   (334 )   (138 )   (604 )   (448 )
Total other income (expense)   (8,984 )   (8,294 )   (16,560 )   (19,887 )

Income (loss) before income tax provision and earnings from
unconsolidated affiliates

(29,633 ) (7,402 ) (37,579 ) (27,537 )
Income tax benefit (expense) (234 ) 149 (297 ) (151 )
Income (loss) from unconsolidated affiliates, net of tax   (5 )   305     266     632  
Net income (loss)   (29,872 )   (6,948 )   (37,610 )   (27,056 )
Other comprehensive income (loss)

Postretirement medical plan amortization of prior service costs

(1,837 ) (1,821 ) (3,675 ) (3,642 )
Income tax on postretirement medical plan        
Other comprehensive income (loss)   (1,837 )   (1,821 )   (3,675 )   (3,642 )
Total comprehensive income (loss) $ (31,709 ) $ (8,769 ) $ (41,285 ) $ (30,698 )
Income (loss) per common share:
Basic $ (0.39 ) $ (0.09 ) $ (0.50 ) $ (0.38 )
Diluted $ (0.39 ) $ (0.09 ) $ (0.50 ) $ (0.38 )
Weighted-average shares outstanding - basic   75,756     75,086     75,544     70,634  
Weighted-average shares outstanding - diluted   75,756     75,086     75,544     70,634  
 
 
CLOUD PEAK ENERGY INC.
UNAUDITED CONDENSED CONSOLIDATED BALANCE SHEETS
(in thousands)
 
        June 30,     December 31,
ASSETS 2018 2017
Current assets
Cash and cash equivalents $ 90,174 $ 107,948
Accounts receivable 41,978 50,075
Due from related parties 696 122
Inventories, net 70,579 72,904
Income tax receivable 476 256
Other prepaid and deferred charges 26,180 36,964
Other assets   803     1,765  
Total current assets 230,886 270,034
 
Noncurrent assets
Property, plant and equipment, net 1,343,846 1,365,755
Goodwill 2,280 2,280
Income tax receivable 29,454 29,454
Other assets   43,043     31,178  
Total assets $ 1,649,509   $ 1,698,701  
 
LIABILITIES AND EQUITY
Current liabilities
Accounts payable $ 32,961 $ 29,832
Royalties and production taxes 53,733 54,327
Accrued expenses 35,340 32,818
Current portion of federal coal lease obligations 379
Other liabilities   1,952     2,435  
Total current liabilities 124,365 119,412
 
Noncurrent liabilities
Senior notes 400,941 405,266
Federal coal lease obligations, net of current portion 1,404
Asset retirement obligations, net of current portion 102,226 99,297
Accumulated postretirement medical benefit obligation, net of
current portion
25,622 24,958
Royalties and production taxes 20,036 21,896
Other liabilities   6,773     20,063  
Total liabilities   681,367     690,892  
 
Equity
Common stock ($0.01 par value; 200,000 shares authorized; 76,255
and 75,644 shares issued and 75,778 and 75,167 outstanding as of
June 30, 2018 and December 31, 2017, respectively) 758 752
Treasury stock, at cost (477 shares as of both June 30, 2018 and
December 31, 2017) (6,498 ) (6,498 )
Additional paid-in capital 654,193 652,702
Retained earnings 309,557 347,046
Accumulated other comprehensive income (loss)   10,132     13,807  
Total equity   968,142     1,007,809  
Total liabilities and equity $ 1,649,509   $ 1,698,701  
 
 
CLOUD PEAK ENERGY INC.
UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS
(in thousands)
 
        Six Months Ended
June 30,
2018     2017
Cash flows from operating activities
Net income (loss) $ (37,610 ) $ (27,056 )

Adjustments to reconcile net income (loss) to net cash provided by
(used in) operating activities:

Depreciation and depletion 29,396 37,894
Accretion 3,411 3,667
Impairments 800
Loss (income) from unconsolidated affiliates, net of tax (266 ) (632 )
Distributions of income from unconsolidated affiliates 1,000 3,500
Equity-based compensation expense 1,878 2,506
(Gain) loss on derivative financial instruments 3,939
Cash received (paid) on derivative financial instrument settlements (1,147 )
Non-cash interest expense related to early retirement of debt and
refinancings
1,611 702
Payment of deferred financing costs (3,621 )
Net periodic postretirement benefit cost (credit) (2,841 ) (2,736 )
Payments for logistics contracts (5,000 ) (17,000 )
Logistics throughput contract amortization expense 8,322 18,998
Other 3,773 4,296
Changes in operating assets and liabilities:
Accounts receivable 8,097 269
Inventories, net 2,307 (1,395 )
Due to or from related parties (574 ) (478 )
Other assets 2,995 (6,160 )
Accounts payable and accrued expenses (9,628 ) (6,100 )
Asset retirement obligations   (482 )   (520 )
Net cash provided by (used in) operating activities   3,568     12,547  
 
Investing activities
Purchases of property, plant and equipment (4,831 ) (7,896 )
Investment in development projects (1,894 ) (2,110 )
Other   69     33  
Net cash provided by (used in) investing activities   (6,656 )   (9,973 )
 
Financing activities
Principal payments on federal coal leases (574 )
Repayment of senior notes (62,094 )
Payment of deferred financing costs (907 ) (406 )
Payment amortized to deferred gain (6,298 ) (6,294 )
Proceeds from issuance of common stock 68,850
Cash paid for equity offering (4,490 )
Other   (1,300 )   (1,312 )
Net cash provided by (used in) financing activities   (9,079 )   (5,746 )
 
Net increase (decrease) in cash, cash equivalents, and restricted
cash
(12,167 ) (3,172 )
Cash, cash equivalents, and restricted cash at beginning of period   108,673     84,433  
Cash, cash equivalents, and restricted cash at end of period $ 96,506   $ 81,261  
 
 
CLOUD PEAK ENERGY INC. AND SUBSIDIARIES
RECONCILIATION OF NON-GAAP MEASURES
(in millions)
 
Adjusted EBITDA
    Three Months Ended     Six Months Ended
June 30, June 30,
2018     2017 2018     2017
Net income (loss) $ (29.9 ) $ (6.9 ) $ (37.6 ) $ (27.1 )
Interest income (0.3 ) (0.1 ) (0.5 ) (0.2 )
Interest expense 10.5 9.9 19.7 22.8
Income tax (benefit) expense 0.2 (0.1 ) 0.3 0.2
Depreciation and depletion   14.4     19.2     29.4     37.9  
EBITDA (5.0 ) 21.9 11.3 33.6
Accretion 1.7 1.8 3.4 3.7
Derivative financial instruments:

Exclusion of fair value mark-to-market losses (gains) (1)

1.6 3.9
Inclusion of cash amounts received (paid) (2)       (0.8 )       (1.1 )
Total derivative financial instruments 0.8 2.8
Impairments 0.8 0.8

Non-cash throughput amortization expense and contract termination
payments

  1.7     5.1     3.4     9.9  
Adjusted EBITDA $ (0.8 ) $ 29.6   $ 18.9   $ 50.0  

______________________

(1)

  Fair value mark-to-market (gains) losses reflected on the Unaudited
Condensed Consolidated Statements of Operations and Comprehensive
Income (Loss).
(2) Cash amounts received and paid reflected within operating cash flows
in the Unaudited Condensed Consolidated Statements of Cash Flows.
 
 
Adjusted EBITDA by Segment
    Three Months Ended     Six Months Ended
June 30, June 30,
2018     2017 2018     2017
Net income (loss) $ (29.9 ) $ (6.9 ) $ (37.6 ) $ (27.1 )
Interest income (0.3 ) (0.1 ) (0.5 ) (0.2 )
Interest expense 10.5 9.9 19.7 22.8
Other, net 0.3 0.1 0.6 0.4
Income tax expense (benefit) 0.2 (0.1 ) 0.3 0.2
Loss (income) from unconsolidated affiliates, net of tax (0.3 ) (0.3 ) (0.6 )

Net periodic postretirement benefit cost (income), excluding
service cost

  (1.6 )   (1.6 )   (3.2 )   (3.2 )
Consolidated operating income (loss) $ (20.6 ) $ 0.9   $ (21.0 ) $ (7.7 )
 
Owned and Operated Mines
Operating income (loss) $ (12.2 ) $ 14.0 $ (11.0 ) $ 24.6
Depreciation and depletion 14.1 19.1 28.8 37.5
Accretion 1.6 1.7 3.2 3.4
Derivative financial instruments:

Exclusion of fair value mark-to-market losses (gains)

1.6 3.9
Inclusion of cash amounts received (paid)       (0.8 )       (1.1 )
Total derivative financial instruments 0.8 2.8
Impairments 0.8 0.8
Net periodic postretirement benefit income (cost), excluding service
cost
1.3 1.3 2.7 2.7
Other   (0.3 )   (0.2 )   (0.6 )   (0.5 )
Adjusted EBITDA $ 5.3   $ 36.7   $ 23.9   $ 70.5  
 
Logistics and Related Activities
Operating income (loss) $ 5.6 $ (3.4 ) $ 11.0 $ (10.9 )
Non-cash throughput amortization expense and contract termination
payments
1.7 5.1 3.4 9.9
Other       (0.1 )       0.1  
Adjusted EBITDA $ 7.3   $ 1.6   $ 14.4   $ (0.9 )
 
Other Unallocated Operating Income (Loss)
Other operating income (loss) $ (13.4 ) $ (10.1 ) $ (21.1 ) $ (21.4 )
Elimination of intersegment operating income (loss) $ (0.6 ) $ 0.5 $ 0.1 $
 
 
Tons Sold                                        
(in thousands) Q2     Q1     Q4     Q3     Q2     Year     Year     Year     Year     Year
2018     2018     2017     2017     2017     2017     2016     2015     2014     2013
Mine
Antelope 4,884 6,660 6,540 7,813 6,711 28,439 29,807 35,167 33,647 31,354
Cordero Rojo 3,348 2,600 3,955 3,770 4,227 16,394 18,332 22,872 34,809 36,670
Spring Creek 3,331 2,999 3,047 3,959 3,390 12,606 10,348 17,027 17,443 18,009
Decker (50% interest) -     -     -     -     -     -     -     -     1,079     1,519
Total 11,563 12,259 13,542 15,542 14,328 57,439 58,488 75,066 86,978 87,552

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