Edgar Filing: CLOUD PEAK ENERGY INC.

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

WASHINGTON, D.C. 20549

FORM 10-Q

(Mark One)

x	QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2013

o	TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from to

Commission File Number: 001-34547

Commission File Number: 333-168639

Cloud Peak Energy Inc.

Cloud Peak Energy Resources LLC

(Exact name of registrant as specified in its charter)

Delaware Delaware		26-3088162 26-4073917
(State or other jurisdiction of		(I.R.S. Employer
incorporation or organization)		Identification No.)

505 S. Gillette Ave., Gillette, Wyoming		82716
(Address of principal executive offices)		(Zip Code)

(307) 687-6000

(Registrant’s telephone number, including area code)

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.

Cloud Peak Energy Inc.		Yes x o No
Cloud Peak Energy Resources LLC		Yes x o 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).

Cloud Peak Energy Inc.		Yes x o No
Cloud Peak Energy Resources LLC		Yes x o No

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 the definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act. (Check one):

	Large accelerated filer	Accelerated filer	Non-accelerated filer (Do not check if a smaller reporting company)	Smaller reporting company
Cloud Peak Energy Inc.	x	o	o	o
Cloud Peak Energy Resources LLC	o	o	x	o

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).

Cloud Peak Energy Inc.		o Yes No x
Cloud Peak Energy Resources LLC		o Yes No x

Number of shares outstanding of Cloud Peak Energy Inc.’s common stock, as of the latest practicable date: Common stock, $0.01 par value per share, 60,835,671 shares outstanding as of July 22, 2013. 100% of the common membership units of Cloud Peak Energy Resources LLC outstanding as of July 22, 2013 are held by Cloud Peak Energy Inc.

This combined Form 10-Q is separately filed by Cloud Peak Energy Inc. and Cloud Peak Energy Resources LLC. Cloud Peak Energy Resources LLC meets the conditions set forth in General Instruction H(1)(a) and (b) of Form 10-Q and is therefore filing this form with the reduced disclosure format allowed under that General Instruction.

Table of Contents

CLOUD PEAK ENERGY INC. AND

CLOUD PEAK ENERGY RESOURCES LLC

TABLE OF CONTENTS

		Page

PART I — FINANCIAL INFORMATION

Item 1	Financial Statements —
	Cloud Peak Energy Inc.
	Cloud Peak Energy Inc. Unaudited Condensed Consolidated Statements of Operations and Comprehensive Income for the Three and Six Months Ended June 30, 2013 and 2012	1
	Cloud Peak Energy Inc. Condensed Consolidated Balance Sheets as of June 30, 2013 (Unaudited) and December 31, 2012 (Audited)	2
	Cloud Peak Energy Inc. Unaudited Condensed Consolidated Statements of Cash Flows for the Six Months Ended June 30, 2013 and 2012	3

	Cloud Peak Energy Resources LLC
	Cloud Peak Energy Resources LLC Unaudited Condensed Consolidated Statements of Operations and Comprehensive Income for the Three and Six Months Ended June 30, 2013 and 2012	4
	Cloud Peak Energy Resources LLC Condensed Consolidated Balance Sheets as of June 30, 2013 (Unaudited) and December 31, 2012 (Audited)	5
	Cloud Peak Energy Resources LLC Unaudited Condensed Consolidated Statements of Cash Flows for the Six Months Ended June 30, 2013 and 2012	6
	Notes to Unaudited Condensed Consolidated Financial Statements of Cloud Peak Energy Inc. and Cloud Peak Energy Resources LLC	7

	Cautionary Notice Regarding Forward-Looking Statements	34

Item 2	Management’s Discussion and Analysis of Financial Condition and Results of Operations	36
Item 3	Quantitative and Qualitative Disclosures About Market Risk	53
Item 4	Controls and Procedures	54

PART II — OTHER INFORMATION

Item 1	Legal Proceedings	55
Item 1A	Risk Factors	55
Item 2	Unregistered Sales of Equity Securities and Use of Proceeds	55
Item 3	Defaults Upon Senior Securities	55
Item 4	Mine Safety Disclosures	55
Item 5	Other Information	55
Item 6	Exhibits	55

Explanatory Note

This combined Form 10-Q is filed by Cloud Peak Energy Inc. and Cloud Peak Energy Resources LLC. Each Registrant hereto is filing on its own behalf all of the information contained in this report that relates to such Registrant. Each Registrant hereto is not filing any information that relates to such other Registrant, and therefore makes no representation as to any such information. Cloud Peak Energy Resources LLC is the sole direct subsidiary of Cloud Peak Energy Inc., providing 100% of Cloud Peak Energy Inc.’s total consolidated revenue for the three and six months ended June 30, 2013 and constituting nearly 100% of Cloud Peak Energy Inc.’s total consolidated assets as of June 30, 2013.

Unless the context indicates otherwise, the terms “Cloud Peak Energy,” the “Company,” “we,” “us,” and “our” refer to both Cloud Peak Energy Inc. and Cloud Peak Energy Resources LLC and their subsidiaries. Discussions or areas of this report that either apply only to Cloud Peak Energy Inc. or Cloud Peak Energy Resources LLC are clearly noted in such sections.

Table of Contents

PART I — FINANCIAL INFORMATION

Item 1. Financial Statements.

CLOUD PEAK ENERGY INC.

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF
OPERATIONS AND COMPREHENSIVE INCOME

(in thousands, except per share data)

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2013			2012			2013			2012
Revenue	$	329,996		$	343,183		$	668,048		$	716,086
Costs and expenses
Cost of product sold (exclusive of depreciation, depletion, and accretion, shown separately)	281,603			266,073			557,631			549,018
Depreciation and depletion	25,459			22,285			48,671			45,675
Accretion	4,126			3,422			8,253			6,070
Derivative mark-to-market gains	(12,284		)	(20,183		)	(25,936		)	(18,127		)
Selling, general and administrative expenses	12,834			12,556			26,442			27,298
Other operating costs	1,191			308			1,301			401
Total costs and expenses	312,929			284,461			616,362			610,335
Operating income	17,067			58,722			51,686			105,751
Other income (expense)
Interest income	63			312			188			758
Interest expense	(10,315		)	(7,936		)	(20,799		)	(13,786		)
Other, net	43			(111		)	(198		)	(53		)
Total other expense	(10,209		)	(7,735		)	(20,809		)	(13,081		)
Income before income tax provision and earnings from unconsolidated affiliates	6,858			50,987			30,877			92,670
Income tax expense	(2,462		)	(18,806		)	(11,297		)	(33,908		)
Earnings from unconsolidated affiliates, net of tax	313			1,497			524			1,534
Net income	4,709			33,678			20,104			60,296
Other comprehensive income
Retiree medical plan amortization of prior service costs	444			394			888			788
Other postretirement plan adjustments	—			—			30			90
Income tax on retiree medical plan and pension adjustments	(160		)	(142		)	(330		)	(316		)
Other comprehensive income	284			252			588			562
Total comprehensive income	$	4,993		$	33,930		$	20,692		$	60,858
Income per common share:
Basic	$	0.08		$	0.56		$	0.33		$	1.00
Diluted	$	0.08		$	0.55		$	0.33		$	0.99
Weighted-average shares outstanding - basic	60,629			60,015			60,619			60,011
Weighted-average shares outstanding - diluted	61,165			60,870			61,123			60,826

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

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CLOUD PEAK ENERGY INC.

CONDENSED CONSOLIDATED BALANCE SHEETS

(in thousands)

	June 30,			December 31,
	2013			2012
	(unaudited)			(audited)
ASSETS
Current assets
Cash and cash equivalents	$	199,747		$	197,691
Investments in marketable securities	80,501			80,341
Accounts receivable	95,886			76,117
Due from related parties	836			1,561
Inventories, net	82,659			81,675
Deferred income taxes	26,538			28,112
Derivative financial instruments	37,252			13,785
Other assets	26,737			16,513
Total current assets	550,156			495,795
Noncurrent assets
Property, plant and equipment, net	1,679,731			1,678,294
Goodwill	35,634			35,634
Deferred income taxes	91,909			101,075
Other assets	44,259			40,525
Total assets	$	2,401,689		$	2,351,323

LIABILITIES AND EQUITY
Current liabilities
Accounts payable	$	62,697		$	49,589
Royalties and production taxes	129,467			129,351
Accrued expenses	58,570			50,364
Current portion of tax agreement liability	19,485			19,485
Current portion of federal coal lease obligations	54,339			63,191
Other liabilities	3,854			2,770
Total current liabilities	328,412			314,750
Noncurrent liabilities
Tax agreement liability, net of current portion	97,053			97,053
Senior notes	596,735			596,506
Federal coal lease obligations, net of current portion	122,928			122,928
Asset retirement obligations, net of current portion	239,576			238,991
Other liabilities	61,846			50,073
Total liabilities	1,446,550			1,420,301
Commitments and Contingencies (Note 9)

Equity
Common stock ($0.01 par value; 200,000 shares authorized; 61,225 and 61,114 shares issued and 60,836 and 60,839 outstanding at June 30, 2013 and December 31, 2012, respectively)	608			608
Treasury stock (389 shares and 276 shares at June 30, 2013 and December 31, 2012, respectively)	(5,650		)	(5,390		)
Additional paid-in capital	554,137			550,452
Retained earnings	425,917			405,813
Accumulated other comprehensive loss	(19,873		)	(20,461		)
Total equity	955,139			931,022
Total liabilities and equity	$	2,401,689		$	2,351,323

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

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CLOUD PEAK ENERGY INC.

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(in thousands)

	Six Months Ended
	June 30,
	2013			2012
Cash flows from operating activities
Net income	$	20,104		$	60,296
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and depletion	48,671			45,675
Accretion	8,253			6,070
Earnings from unconsolidated affiliates	(524		)	(1,534		)
Distributions of income from unconsolidated affiliates	2,000			—
Deferred income taxes	10,114			23,679
Stock compensation expense	3,747			6,371
Derivative mark-to-market gains	(25,936		)	(18,127		)
Other	6,879			5,812
Changes in operating assets and liabilities:
Accounts receivable	(19,909		)	4,038
Inventories, net	(833		)	(6,171		)
Due to or from related parties	725			28
Other assets	(10,587		)	(13,225		)
Accounts payable and accrued expenses	(371		)	(29,214		)
Asset retirement obligations	(555		)	(2,940		)
Cash received for financial derivative instruments	2,529			524
Net cash provided by operating activities	44,307			81,282

Investing activities
Acquisition of Youngs Creek and CX Ranch coal and land assets	—			(300,259		)
Purchases of property, plant and equipment	(24,475		)	(21,875		)
Cash paid for capitalized interest	(8,263		)	(36,477		)
Investments in marketable securities	(32,961		)	(53,854		)
Maturity and redemption of investments	32,801			28,887
Investment in project development	(4,087		)	—
Return of restricted cash	—			71,244
Partnership escrow deposit	—			(4,470		)
Return of partnership escrow	4,468			—
Other	63			1,825
Net cash used in investing activities	(32,454		)	(314,979		)

Financing activities
Principal payments on federal coal leases	(8,852		)	(48,959		)
Payment of deferred financing fees	(865		)	—
Other	(80		)	—
Net cash used in financing activities	(9,797		)	(48,959		)

Net increase (decrease) in cash and cash equivalents	2,056			(282,656		)
Cash and cash equivalents at beginning of period	197,691			404,240
Cash and cash equivalents at end of period	$	199,747		$	121,584

Supplemental cash flow disclosures:
Interest paid	$	27,259		$	46,616
Income taxes paid	$	10,377		$	20,788
Supplemental noncash investing and financing activities:
Non-cash interest capitalized	$	8,240		$	9,635
Capital expenditures included in accounts payable	$	7,194		$	4,363
Assets acquired under capital leases	$	7,601		$	—

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

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CLOUD PEAK ENERGY RESOURCES LLC

(SUBSIDIARY OF CLOUD PEAK ENERGY INC.)

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF
OPERATIONS AND COMPREHENSIVE INCOME

(in thousands)

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2013			2012			2013			2012
Revenue	$	329,996		$	343,183		$	668,048		$	716,086
Costs and expenses
Cost of product sold (exclusive of depreciation, depletion, and accretion, shown separately)	281,603			266,073			557,631			549,018
Depreciation and depletion	25,459			22,285			48,671			45,675
Accretion	4,126			3,422			8,253			6,070
Derivative mark-to-market gains	(12,284		)	(20,183		)	(25,936		)	(18,127		)
Selling, general and administrative expenses	12,834			12,556			26,442			27,298
Other operating costs	1,191			308			1,301			401
Total costs and expenses	312,929			284,461			616,362			610,335
Operating income	17,067			58,722			51,686			105,751
Other income (expense)
Interest income	63			312			188			758
Interest expense	(10,315		)	(7,936		)	(20,799		)	(13,786		)
Other, net	43			(111		)	(198		)	(53		)
Total other expense	(10,209		)	(7,735		)	(20,809		)	(13,081		)
Income before income tax provision and earnings from unconsolidated affiliates	6,858			50,987			30,877			92,670
Income tax expense	(2,462		)	(18,806		)	(11,297		)	(33,908		)
Earnings from unconsolidated affiliates, net of tax	313			1,497			524			1,534
Net income	4,709			33,678			20,104			60,296
Other comprehensive income
Retiree medical plan amortization of prior service costs	444			394			888			788
Other postretirement plan adjustments	—			—			30			90
Income tax on retiree medical plan and pension adjustments	(160		)	(142		)	(330		)	(316		)
Other comprehensive income	284			252			588			562
Total comprehensive income	$	4,993		$	33,930		$	20,692		$	60,858

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

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CLOUD PEAK ENERGY RESOURCES LLC

(SUBSIDIARY OF CLOUD PEAK ENERGY INC.)

CONDENSED CONSOLIDATED BALANCE SHEETS

(in thousands)

	June 30,			December 31,
	2013			2012
	(unaudited)			(audited)
ASSETS
Current assets
Cash and cash equivalents	$	199,747		$	197,691
Investments in marketable securities	80,501			80,341
Accounts receivable	95,886			76,117
Due from related parties	836			1,561
Inventories, net	82,659			81,675
Deferred income taxes	19,523			21,096
Derivative financial instruments	37,252			13,785
Other assets	21,333			16,224
Total current assets	537,737			488,490

Noncurrent assets
Property, plant and equipment, net	1,679,731			1,678,294
Goodwill	35,634			35,634
Deferred income taxes	56,970			66,136
Other assets	44,210			40,478
Total assets	$	2,354,282		$	2,309,032

LIABILITIES AND EQUITY
Current liabilities
Accounts payable	$	62,697		$	49,571
Royalties and production taxes	129,467			129,351
Accrued expenses	56,659			43,908
Due to related parties	6,299			12,554
Current portion of federal coal lease obligations	54,339			63,191
Other liabilities	3,854			2,769
Total current liabilities	313,315			301,344

Noncurrent liabilities
Senior notes	596,735			596,506
Federal coal lease obligations, net of current portion	122,928			122,928
Asset retirement obligations, net of current portion	239,576			238,991
Other liabilities	61,846			50,073
Total liabilities	1,334,400			1,309,842
Commitments and Contingencies (Note 9)

Equity
Member’s equity	1,039,755			1,019,651
Accumulated other comprehensive loss	(19,873		)	(20,461		)
Total member’s equity	1,019,882			999,190
Total liabilities and member’s equity	$	2,354,282		$	2,309,032

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

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CLOUD PEAK ENERGY RESOURCES LLC

(SUBSIDIARY OF CLOUD PEAK ENERGY INC.)

UNAUDITED CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(in thousands)

	Six Months Ended
	June 30,
	2013			2012
Cash flows from operating activities
Net income	$	20,104		$	60,296
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and depletion	48,671			45,675
Accretion	8,253			6,070
Earnings from unconsolidated affiliates	(524		)	(1,534		)
Distributions of income from unconsolidated affiliates	2,000			—
Deferred income taxes	10,114			23,679
Derivative mark-to-market gains	(25,936		)	(18,127		)
Other	6,879			5,812
Changes in operating assets and liabilities:
Accounts receivable	(19,909		)	4,038
Inventories, net	(833		)	(6,171		)
Due to or from related parties	(5,530		)	(5,465		)
Other assets	(5,473		)	(11,765		)
Accounts payable and accrued expenses	4,527			(18,810		)
Asset retirement obligations	(555		)	(2,940		)
Cash received for financial derivative instruments	2,529			524
Net cash provided by operating activities	44,317			81,282

Investing activities
Acquisition of Youngs Creek and CX Ranch coal and land assets	—			(300,259		)
Purchases of property, plant and equipment	(24,475		)	(21,875		)
Cash paid for capitalized interest	(8,263		)	(36,477		)
Investments in marketable securities	(32,961		)	(53,854		)
Maturity and redemption of investments	32,801			28,887
Investment in project development	(4,087		)	—
Return of restricted cash	—			71,244
Partnership escrow deposit	—			(4,470		)
Return of partnership escrow	4,468			—
Other	63			1,825
Net cash used in investing activities	(32,454		)	(314,979		)

Financing activities
Principal payments on federal coal leases	(8,852		)	(48,959		)
Payment of deferred financing fees	(865		)	—
Other	(90		)	—
Net cash used in financing activities	(9,807		)	(48,959		)

Net increase (decrease) in cash and cash equivalents	2,056			(282,656		)
Cash and cash equivalents at beginning of period	197,691			404,240
Cash and cash equivalents at end of period	$	199,747		$	121,584

Supplemental cash flow disclosures:
Interest paid	$	27,259		$	46,616

Supplemental noncash investing and financing activities:
Non-cash interest capitalized	$	8,240		$	9,635
Capital expenditures included in accounts payable	$	7,194		$	4,363
Assets acquired under capital lease	$	7,601		$	—

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

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CLOUD PEAK ENERGY INC. AND

CLOUD PEAK ENERGY RESOURCES LLC

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

1. Organization and Business

CPE Inc. is one of the largest producers of coal in the United States of America (“U.S.”) and the Powder River Basin (“PRB”), based on our 2012 coal sales. We operate some of the safest mines in the coal industry. According to MSHA data, in 2012, we had one of the lowest employee all injury incident rates among the largest U.S. coal producing companies.

We currently operate solely in the PRB, the lowest cost region of the major coal producing regions in the U.S., where we operate three wholly-owned surface coal mines, the Antelope mine, the Cordero Rojo mine and the Spring Creek mine. We also have two major development projects, the Youngs Creek project and the Crow project. We also own a 50% non-operating interest in the Decker mine, which we have contracted to sell to the other 50% owner, see Note 9.

Our Antelope and Cordero Rojo mines are located in Wyoming and are two of the four largest coal mines in the U.S. Our Spring Creek mine is located in Montana. Our logistics business is the largest U.S. exporter of thermal coal into South Korea. Our mines produce subbituminous thermal coal with low sulfur content, and we sell our coal primarily to domestic and foreign electric utilities. We do not produce any metallurgical coal. Thermal coal is primarily consumed by electric utilities and industrial consumers as fuel for electricity generation and steam output. In 2012, the coal we produced generated approximately 4% of the electricity produced in the U.S. As of December 31, 2012, we controlled approximately 1.3 billion tons of proven and probable reserves. For information regarding our revenue and long-lived assets by geographic area, as well as revenue from external customers, Adjusted EBITDA and total assets by segment, please see Note 14.

During 2012, we acquired rights to substantial undeveloped coal and complementary surface assets in the Northern PRB (“Youngs Creek project”). In January 2013, we executed an option to lease agreement (“Option Agreement”) and a corresponding exploration agreement (“Exploration Agreement”) with the Crow Tribe of Indians, which was approved by the Department of the Interior on June 14, 2013. This coal project (“Crow project”) is located on the Crow Indian Reservation in southeast Montana, near our Spring Creek mine and Youngs Creek project. We are in the process of evaluating the development options for the Youngs Creek project and the Crow project, but believe that their proximity to the Spring Creek mine represents an opportunity to optimize our mine developments in the Northern PRB.

For purposes of this report, the term “Northern PRB” refers to the area within the PRB that lies within Montana and the northern part of Sheridan County, Wyoming. Our Spring Creek mine, the Decker mine, the Youngs Creek project and the Crow project are located in the Northern PRB.

We continue to seek ways to increase our future export capacity through existing and proposed new Pacific Northwest export terminals, including our option agreement with SSA Marine. This throughput option agreement with SSA Marine provides us with an option for up to 16 million tonnes of capacity per year through the planned dry bulk cargo Gateway Pacific Terminal at Cherry Point in the State of Washington. Our potential share of capacity will depend upon the ultimate capacity of the terminal and is subject to the terms of the option agreement. The terminal would accommodate cape size vessels. Our option is exercisable following future permit completion for the terminal, the timing of which is uncertain.

Basis of Presentation

CPE Inc. conducts all of its business through CPE Resources and its subsidiaries. CPE Inc.’s consolidated financial statements are substantially identical to CPE Resources’s consolidated financial statements, with the following exceptions:

· Tax agreement liability and deferred tax assets relating thereto

· Earnings per share (see Note 13)

· Equity-based compensation (see Note 15)

· Supplemental guarantor information (see Note 16)

Principles of Consolidation

We consolidate the accounts of entities in which we have a controlling financial interest under the voting control model. We account for our 50% non-operating interest in Decker Coal Company (“Decker”) using the proportionate consolidation method, whereby our share of Decker’s assets, liabilities, revenue and expenses are included in our

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CLOUD PEAK ENERGY INC. AND

CLOUD PEAK ENERGY RESOURCES LLC

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

consolidated financial statements. Investments in other entities that we do not control but have the ability to exercise significant influence over the investee’s operating and financial policies are accounted for under the equity method. All intercompany balances and transactions have been eliminated in the consolidated financial statements.

The interim period unaudited condensed consolidated financial statements have been prepared in conformity with accounting principles generally accepted in the U.S. (“U.S. GAAP”). In accordance with U.S. GAAP for interim financial statements, these unaudited condensed consolidated financial statements do not include certain information and note disclosures that are normally included in annual financial statements prepared in conformity with U.S. GAAP. The year-end condensed consolidated balance sheet data was derived from audited consolidated financial statements, but does not include all footnote disclosures required to be included in annual financial statements by U.S. GAAP. Accordingly, these unaudited condensed consolidated financial statements should be read in conjunction with the audited consolidated financial statements as of December 31, 2012 and 2011, and for each of the three years ended December 31, 2012, included in our Annual Report on Form 10-K for the year ended December 31, 2012 (“2012 Form 10-K”). In the opinion of management, the accompanying unaudited condensed consolidated financial statements contain all adjustments, which are of a normal and recurring nature, necessary to present fairly the financial position as of June 30, 2013, the results of operations and comprehensive income for the three and six months ended June 30, 2013 and 2012, and the cash flows for the six months ended June 30, 2013 and 2012, in conformity with U.S. GAAP.

The preparation of financial statements in conformity with U.S. GAAP requires management to make estimates and assumptions that affect reported amounts. These estimates and assumptions are based on information available as of the date of the financial statements. Our forecasts are key input assumptions in several balance sheet estimates, including our Asset retirement obligations, Tax agreement liability and the carrying value of assets. As we finalize our forecasts during the third quarter, which may include reduced production at our Cordero Rojo mine, we will update our balance sheet estimates accordingly. Accounting measurements at interim dates inherently involve greater reliance on estimates than at year-end. The results of operations for the six months ended June 30, 2013 are not necessarily indicative of results that can be expected for the full year. Please refer to the section entitled “Critical Accounting Policies and Estimates” of “Management’s Discussion and Analysis of Financial Condition and Results of Operations” in our 2012 Form 10-K for a discussion of our critical accounting policies and estimates.

Certain amounts have been reclassified to conform to current period presentation. Due to the tabular presentation of rounded amounts, certain tables reflect insignificant rounding differences.

2. Accounting Policies and Standards Update

Recently Issued Accounting Pronouncements

From time to time, the Financial Accounting Standards Board (“FASB”) or other standard setting bodies issue new accounting pronouncements. Updates to the FASB Accounting Standards Codification are communicated through issuance of an Accounting Standards Update (“ASU”). Unless otherwise discussed, we believe that the impact of recently issued guidance, whether adopted or to be adopted in the future, is not expected to be material to our consolidated financial statements upon adoption.

Offsetting Assets and Liabilities

In December 2011, the FASB issued ASU No. 2011-11, Balance Sheet (Topic 210): Disclosures about Offsetting Assets and Liabilities. In January 2013, the FASB issued ASU 2013-01, Balance Sheet (Topic 210): Clarifying the Scope of Disclosures about Offsetting Assets and Liabilities. ASU 2011-11, as clarified by ASU 2013-01, requires an entity to disclose information about offsetting and related arrangements to enable users of financial statements to understand the effect of those arrangements on its financial position, and to allow investors to better compare financial statements prepared under U.S. GAAP with financial statements prepared under International Financial Reporting Standards (IFRS). The new standards are effective for annual periods beginning January 1, 2013 and interim periods within those annual periods. Retrospective application is required. As this accounting standard only requires enhanced disclosure, which is included in Note 4, the adoption of this standard did not impact our financial position or results of operations.

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Other Comprehensive Income

In February 2013, the FASB issued ASU 2013-02, Comprehensive Income (Topic 220): Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income. This guidance requires disclosure of amounts reclassified out of accumulated other comprehensive income by component. In addition, an entity is required to present either on the face of the statement of operations or in the notes, significant amounts reclassified out of accumulated other comprehensive income by the respective line items of net income but only if the amount reclassified is required to be reclassified to net income in its entirety in the same reporting period. For amounts not reclassified in their entirety to net income, an entity is required to cross-reference to other disclosures that provide additional detail about those amounts. This guidance is effective prospectively for annual and interim periods beginning January 1, 2013. As this accounting standard only requires enhanced disclosure, which is included in Note 12, the adoption of this standard did not impact our financial position or results of operations.

3. Inventories

Inventories, net, consisted of the following (in thousands):

	June 30,			December 31,
	2013			2012
Materials and supplies	$	79,423		$	76,989
Less: Obsolescence allowance	(1,052		)	(834		)
Material and supplies, net	78,371			76,155
Coal inventory	4,287			5,519
Inventories, net	$	82,659		$	81,675

4. Derivatives

We are exposed to various types of risk in the normal course of business, including fluctuations in commodity prices and particularly the prices we receive for our coal sales, both domestically and internationally, and the prices we pay for our consumption of certain raw materials such as diesel fuel. We seek to manage some of the volatility of these fluctuations by using derivative financial instruments.

All of our derivative financial instruments are recognized in the balance sheet at fair value. As mark-to-market accounting is applied, changes in the fair value of the derivative financial instruments are included in “Operating income” on the consolidated statements of operations and comprehensive income each period.

Coal Contracts

We use international coal forward contracts linked to Newcastle coal prices to help manage our exposure to variability in future international coal prices. We use domestic coal futures contracts referenced to the 8800 Btu coal price sold from the PRB, as quoted on the Chicago Mercantile Exchange, to help manage our exposure to market changes in domestic coal prices. At June 30, 2013, we held coal derivative positions that are expected to settle in the following years (in thousands):

	2013		2014		2015		2016		Total
International Coal Forward Contracts
Notional amount (tons)	558		1,190		344		132		2,224
Net asset position	$	10,981	$	17,350	$	6,583	$	2,272	$	37,185

Domestic Coal Futures Contracts
Notional amount (tons)	—		1,080		180		—		1,260

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WTI Collars

We use costless collars to help manage our exposure to market changes in diesel fuel prices. The collars are indexed to the West Texas Intermediate (“WTI”) crude oil price as quoted on the New York Mercantile Exchange. As such, the nature of the collar does not directly offset market changes to our diesel costs. Under a collar agreement, we pay the difference between the monthly average index price and a floor price if the index price is below the floor, and we receive the difference between the ceiling price and the monthly average index price if the index price is above the ceiling price. No amounts are paid or received if the index price is between the floor and ceiling prices. While we would not receive the full benefit of extreme price decreases, the collars mitigate the risk of extreme crude oil price increases and thereby increased diesel costs that would otherwise have a negative impact on our cash flow. At June 30, 2013, we held the following WTI collars (in thousands except per barrel amounts):

Settlement	Notional	Weighted-Average per Barrel
Period	Amount	Floor		Ceiling
	(barrels)
2013	264	$	71.97	$	112.01
2014	288	70.34		111.26
Total	552	$	71.12	$	111.62

Offsetting and Balance Sheet Presentation

	June 30, 2013
	Gross Amounts of Recognized					Gross Amounts Offset in the Consolidated Balance Sheet					Net Amounts Presented in the Consolidated Balance Sheet
	Assets		Liabilities			Assets			Liabilities		Assets		Liabilities

International coal forward contracts	$	38,677	$	(1,492	)	$	(1,492	)	$	1,492	$	37,185	$	—
WTI collars	73		(67		)	(7		)	7		66		(60		)
Total	$	38,750	$	(1,558	)	$	(1,498	)	$	1,498	$	37,252	$	(60	)

	December 31, 2012
	Gross Amounts of Recognized					Gross Amounts Offset in the Consolidated Balance Sheet					Net Amounts Presented in the Consolidated Balance Sheet
	Assets		Liabilities			Assets			Liabilities		Assets		Liabilities

International coal forward contracts	$	13,677	$	(30	)	$	(30	)	$	30	$	13,647	$	—
WTI collars	138		—			—			—		138		—
Total	$	13,815	$	(30	)	$	(30	)	$	30	$	13,785	$	—

Net amounts of international coal forward contracts and WTI collar assets are included in the Derivative financial instruments line in the consolidated balance sheets. Net amounts of WTI collar liabilities are included in other current liabilities in the consolidated balance sheets. Amounts due to us or to the exchange as a result of changes in the market price of our open domestic coal futures contracts and to fulfill margin requirements are received or paid through our brokerage bank on a daily basis; therefore, there is no asset or liability on the balance sheets. There were no cash collateral requirements at June 30, 2013 or December 31, 2012.

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Derivative Gains and Losses

Derivative mark-to-market (gains) and losses recognized in the consolidated statement of operations and comprehensive income were (in thousands):

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2013			2012			2013			2012
International coal forward contracts	$	(12,402	)	$	(20,119	)	$	(26,184	)	$	(18,063	)
Domestic coal futures contracts	93			—			117			—
WTI collars	25			(64		)	132			(64		)
Total	$	(12,284	)	$	(20,183	)	$	(25,936	)	$	(18,127	)

See Note 5 for a discussion related to the fair value of derivative financial instruments.

5. Fair Value of Financial Instruments

Due to the short term nature of certain of our financial instruments, including cash and cash equivalents, accounts receivable, amounts due from related parties, accounts payable, and certain current liabilities, we believe that their historical cost approximated fair value.

We also held investments in marketable securities and derivative financial instruments that we assessed and reported on our balance sheet at fair value as of June 30, 2013 and December 31, 2012. We use a three-level fair value hierarchy that categorizes assets and liabilities measured at fair value based on the observability of the inputs utilized in the valuation. The levels of the hierarchy, as defined below, give the highest priority to unadjusted quoted prices in active markets for identical assets or liabilities and the lowest priority to unobservable inputs.

· Level 1 is defined as observable inputs such as quoted prices in active markets for identical assets. Level 1 assets include investments in trading securities, primarily asset-backed securities.

· Level 2 is defined as observable inputs other than Level 1 prices. These include quoted prices for similar assets or liabilities in an active market, quoted prices for identical assets and liabilities in markets that are not active, or other inputs that are observable or can be corroborated by observable market data for substantially the full term of the assets or liabilities. Our Level 2 assets and liabilities include derivative financial instruments with fair values derived from quoted prices in over-the-counter markets or from prices received from direct broker quotes.

· Level 3 is defined as unobservable inputs in which little or no market data exists, therefore requiring an entity to develop its own assumptions. We had no Level 3 investments as of June 30, 2013 or December 31, 2012.

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The tables below set forth, by level, our financial assets and liabilities that are recorded at fair value in the accompanying condensed consolidated balance sheets (in thousands). As required by accounting guidance, assets and liabilities are classified in their entirety based on the lowest level of input that is significant to the fair value measurement.

	Fair Value at June 30, 2013
Description	Level 1		Level 2		Total
Assets
Money market funds(1)	$	110,415	$	—	$	110,415
Derivative financial instruments	$	—	$	37,252	$	37,252
Investments in marketable securities	$	—	$	80,501	$	80,501
Liabilities
Derivative financial instruments	$	—	$	60	$	60

	Fair Value at December 31, 2012
Description	Level 1		Level 2		Total
Assets
Money market funds(1)	$	145,422	$	—	$	145,422
Derivative financial instruments	$	—	$	13,785	$	13,785
Investments in marketable securities	$	—	$	80,341	$	80,341

(1) Included in cash and cash equivalents in the consolidated balance sheets along with $89.3 million and $52.3 million of demand deposits at June 30, 2013 and December 31, 2012, respectively.

We did not have any transfers between levels during the six months ended June 30, 2013. Our policy is to value all transfers between levels using the beginning of period valuation.

6. Long-Term Debt

Long-term debt consisted of the following (in thousands):

	June 30, 2013						December 31, 2012
	Principal		Carrying Value		Fair Value(1)		Principal		Carrying Value		Fair Value(1)
8.25% Senior Notes due 2017, net of unamortized discount	$	300,000	$	298,596	$	318,000	$	300,000	$	298,471	$	329,418

8.50% Senior Notes due 2019, net of unamortized discount	300,000		298,139		320,250		300,000		298,035		332,700
Total long-term debt	$	600,000	$	596,735	$	638,250	$	600,000	$	596,506	$	662,118

(1) The fair value of the senior notes was based on observable market inputs, which are considered Level 2 in the fair value hierarchy.

7. Other Short-Term and Long-Term Obligations

Federal Coal Lease Obligations

Federal coal lease obligations consisted of (in thousands):

	June 30,		December 31,
	2013		2012
Federal coal lease obligations, current	$	54,339	$	63,191
Federal coal lease obligations, noncurrent	122,928		122,928
Total federal coal lease obligations	$	177,267	$	186,119

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Our federal coal lease obligations, as reflected in the consolidated balance sheets, consist of obligations payable to the Bureau of Land Management of the U.S. Department of the Interior (the “BLM”) discounted at an imputed interest rate. Imputed interest is included in accrued expenses.

We have federal coal lease payments, as follows (dollars in thousands):

					June 30, 2013				December 31, 2012
	Annual		Imputed		Carrying		Fair		Carrying		Fair
Payment Dates	Payment		Interest Rate		Value		Value(1)		Value		Value(1)
May 1, 2009 — 2013	$	9,620	8.70	%	$	—	$	—	$	8,852	$	9,532
July 1, 2011 — 2015	$	59,545	8.50	%	152,078		174,744		152,078		171,075
September 1, 2011 — 2015	$	9,862	8.50	%	25,189		28,519		25,189		28,196
					$	177,267	$	203,263	$	186,119	$	208,803

(1) The fair value of estimates for federal coal lease obligations was determined by discounting the remaining lease payments using the then current estimate of the credit-adjusted, risk-free rate based on our then current credit rating, which are considered Level 2 in the fair value hierarchy.

Future payments on federal coal leases are as follows (in thousands):

Year Ended December 31,
2013	$	69,407
2014	69,407
2015	69,407
Total	208,221
Less: imputed interest	30,954
Total principal payments	177,267
Less: current portion	54,339
Long-term federal coal leases payable	$	122,928

Capital Equipment Lease Obligations

During the three months ended June 30, 2013, we entered into capital leases on equipment under various lease schedules, which are subject to the master lease agreement, and are pre-payable at our option. Interest on the leases is based on the one-month LIBOR plus 1.95% for an annual rate of 2.14% as of June 30, 2013. The gross value of property, plant, and equipment under capital leases was $7.6 million as of June 30, 2013 and related primarily to the leasing of mining equipment. The accumulated depreciation for these items was $0.2 million at June 30, 2013, and changes thereto have been included in Depreciation, depletion and amortization in the consolidated statements of operations. Due to the variable nature of the imputed interest, fair value is equal to carrying value.

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Capital equipment lease obligations consisted of (in thousands):

Year Ended December 31,
2013	$	621
2014	1,225
2015	1,201
2016	1,178
2017	1,155
Thereafter	2,694
Total	8,074
Less: interest	563
Total principal payments	7,511
Less: current portion	1,086
Long-term capital equipment lease obligations	$	6,425

Accounts Receivable Securitization

On February 11, 2013, we executed an Accounts Receivable Securitization Facility (“A/R Securitization Program”) with capacity of up to $75 million. CPE Resources and certain of our subsidiaries are parties to the A/R Securitization Program. In January 2013, we formed CPE Receivables LLC (the “SPE”), a special purpose, bankruptcy-remote wholly-owned subsidiary, to purchase, subject to certain exclusions, in a true sale, trade receivables generated by certain of our subsidiaries without recourse (other than customary indemnification obligations for breaches of specific representations and warranties), and then transfer undivided interests in up to $75 million of those accounts receivable to a financial institution for cash borrowings for our ultimate benefit. The total aggregate borrowings are limited by eligible accounts receivable, as defined under the terms of the A/R Securitization Program. At June 30, 2013, the A/R Securitization Program would have allowed for $51.9 million of borrowing capacity. There were no borrowings from the A/R Securitization Program at June 30, 2013. The SPE is consolidated into our financial statements.

Amended Credit Agreement

Our Amended Credit Agreement establishes a commitment to provide us with a senior secured revolving credit facility with a capacity of up to a $500 million, which can be used to borrow funds or issue letters of credit. The financial covenants in the Amended Credit Agreement are based on EBITDA (which is defined in the Amended Credit Agreement and is not the same as EBITDA or Adjusted EBITDA otherwise presented), requiring us to maintain defined minimum levels of interest coverage and providing for a limitation on our leverage ratio. The borrowing capacity under the Amended Credit Agreement is reduced by the amount of letters of credit issued and is limited by the covenant ratio of funded debt to EBITDA. As of June 30, 2013, our borrowing capacity under the Amended Credit Agreement and the A/R Securitization Program was approximately $487 million. Our obligations under the credit facility are secured by substantially all of CPE Resources’s assets and substantially all of the assets of certain of CPE Resources’s subsidiaries, subject to certain permitted liens and customary exceptions for similar coal financings. Our obligations under the credit facility are also supported by a guarantee by CPE Resources’s domestic restricted subsidiaries. The credit facility matures on June 3, 2016. As of June 30, 2013, no borrowings were outstanding under the credit facility and we were in compliance with the covenants contained in our Amended Credit Agreement.

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8. Asset Retirement Obligations

Changes in the carrying amount of our AROs were as follows (in thousands):

	2013
Balance at January 1,	$	240,634
Accretion expense	8,253
Revisions to estimated cash flows	(2,056		)
Payments	(555		)
Balance at June 30,	246,276
Less: current portion	(6,700		)
Asset retirement obligation, net of current portion	$	239,576

Revisions to estimated cash flows pertain to revisions in the estimated amount and timing of legally required reclamation activities throughout the lives of the respective mines and reflect changes in estimates of closure volumes, disturbed acreages, and third-party unit costs as of June 30, 2013.

9. Commitments and Contingencies

Commitments

Purchase Commitments

We had outstanding purchase commitments consisting of (in thousands):

	June 30,		December 31,
	2013		2012
Capital commitments
Equipment	$	12,636	$	20,317
Land	23,700		23,700

Supplies and services
Coal purchase commitments	$	21,143	$	28,633
Transportation agreements	229,307		159,398
Materials and supplies	24,561		24,552

Contingencies

Litigation

Sierra Club Clean Water Act Citizen Suit

On June 4, 2013, Sierra Club, Puget Soundkeeper Alliance, RE Sources for Sustainable Communities, Columbia Riverkeeper, and Friends of the Columbia Gorge (collectively “Plaintiffs”) filed a citizen suit against Burlington Northern Santa Fe Railway Company (“BNSF”), Peabody Energy, Inc., Global Mining Holding Co., LLC, Ambre Energy North America, Inc., Cloud Peak Energy Inc., and First Energy Corp. (collectively, “Defendants”) in the U.S. District Court for the Western District of Washington alleging violations of the Clean Water Act.

In their complaint, Plaintiffs allege that coal-bearing rail cars transported by BNSF from the PRB in Wyoming and Montana to electric utilities and export terminals in Washington state and British Columbia, Canada, release coal dust, coal chunks, and other substances related to the treatment and transportation of coal (collectively, “coal particles”) into rivers, lakes, and other waters in Washington state without a Clean Water Act permit. The complaint alleges that the coal particles are released from BNSF railcars through holes in the bottoms and sides of the rail cars, and from the open tops of the rail cars.

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Plaintiffs’ complaint asks the court to issue a declaratory judgment that Defendants have violated the Clean Water Act, and issue injunctive relief preventing Defendants from operating rail cars and trains in a manner that will result in future discharges of coal particles into jurisdictional waters in Washington state. The complaint also asks the court to order Defendants to remove coal deposits from the relevant waters, and to impose civil penalties.

On July 29, 2013, Plaintiffs filed a notice of voluntary dismissal and amended complaint dismissing their claims against Cloud Peak Energy and the other coal producers without prejudice and naming BNSF as the sole defendant. Cloud Peak Energy believes Plaintiffs’ challenge against BNSF is without merit.

Decker Litigation

On July 9, 2012, our wholly-owned indirect subsidiary, Western Minerals LLC (“Western Minerals”), filed a lawsuit in the U.S. District Court for the District of Montana (Billings Division), against KCP Inc. (“KCP”), its 50% joint-venture partner in the Decker mine in Montana. Western Minerals also named as defendants KCP’s parent companies, Ambre Energy North America, Inc. (“Ambre N.A.”) and Ambre Energy Limited (“Ambre Limited” and together with Ambre N.A. “Ambre”). In its complaint, Western Minerals alleges that KCP and Ambre are engaging in self-dealing and other wrongful conduct in breach of the Decker joint venture agreement and other legal duties owed to the joint venture and its 50/50 owners. Western Minerals asserts claims for breach of contract, breach of implied covenant of good faith and fair dealing, breach of fiduciary duty, aiding and abetting breach of fiduciary duty, civil conspiracy, and a request for an accounting of, among other things, unauthorized Decker expenditures and Ambre’s proposed self-dealing transactions concerning sales of Decker coal to Ambre and its affiliates. Western Minerals seeks both unspecified monetary damages and injunctive relief.

On August 23, 2012, KCP and Ambre N.A., filed an amended answer to Western Minerals’ complaint, replacing the original answer they filed on July 30, 2012. In their amended answer, KCP and Ambre N.A. deny the principal allegations of Western Minerals. Additionally, KCP asserted six counterclaims against Western Minerals: breach of contract, breach of the covenant of good faith and fair dealing, breach of fiduciary duty, dissolution of the joint venture, civil conspiracy and a request for declaratory judgment. KCP also asserted two third-party claims against CPE Inc. for tortious interference of economic relations and civil conspiracy involving unnamed “John Doe” defendants. In general, KCP alleges that Western Minerals is frustrating the operation of the Decker mine to benefit Cloud Peak Energy’s Spring Creek mine and export opportunities. Aside from the request that the court disassociate and expel Western Minerals from the Decker mine joint venture, KCP also seeks unspecified monetary damages in its counterclaims. Western Minerals and Cloud Peak Energy believe KCP’s claims are without merit and intend to vigorously defend them. On September 14, 2012, Ambre Limited filed a motion to dismiss arguing that it was not subject to the jurisdiction of the Montana federal court. Western Minerals has filed a response to that motion and the court has not yet issued a ruling.

On December 5, 2012, we and Ambre Limited announced that our respective companies have entered into agreements for Ambre Limited to purchase our 50% interest in the Decker mine and related assets and assume all reclamation liabilities. The agreements would also provide for the joint resolution and dismissal of the pending Decker litigation upon closing of the transaction. The potential transaction has not been completed and the parties are currently in discussions. The timing of any closing is uncertain and is anticipated to depend on Ambre’s ability to finance the cash collateral necessary to replace our outstanding reclamation and lease bonds for the Decker mine.

West Antelope II LBA Challenges

Challenges Against the BLM’s Leasing Process; Intervention by Cloud Peak Energy and Others — On May 3, 2010, WildEarth Guardians, Defenders of Wildlife and Sierra Club (collectively, “WildEarth”) and the Powder River Basin Resource Council (“PRBRC”) filed appeals with the Interior Board of Land Appeals (“IBLA”) regarding the U.S. Bureau of Land Management’s (“BLM”) decision to offer the West Antelope II (“WAII”) coal tracts for lease. On June 29, 2010, WildEarth voluntarily dismissed its appeal. On July 13, 2010, WildEarth filed a complaint in the United States District Court for the District of Columbia (“D.C. District Court”) challenging the BLM’s decision. On November 2, 2010, the IBLA issued a decision in PRBRC’s appeal, rejecting all of PRBRC’s arguments and affirming the BLM’s decision in all respects. On January 3, 2011, PRBRC filed a complaint in the D.C. District Court appealing the IBLA decision. On May 8, 2011, the D.C. District Court consolidated the WildEarth and PRBRC challenges. Antelope Coal LLC, a wholly-owned subsidiary of

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CPE Resources, (along with the National Mining Association and the State of Wyoming) intervened in the consolidated action on the side of the BLM. In the consolidated action, WildEarth and PRBRC requested that the court vacate the BLM’s authorization, sale and issuance of the WAII leases and enjoin any coal mining activity on the leases until the BLM and the U.S. Fish and Wildlife Service had undertaken additional environmental analysis requested by the plaintiff organizations.

Award of LBAs to Cloud Peak Energy — On May 11, 2011, the BLM held a competitive sale for the WAII North Tract. On June 15, 2011, the BLM held a competitive sale for the WAII South Tract. Antelope Coal LLC was the successful high bidder in both sales, and the BLM issued leases to Antelope Coal LLC for the North Tract effective July 1, 2011 and for South Tract effective September 1, 2011.

District Court Rejection of Challenges; Appeal by Plaintiffs — On July 30, 2012, the D.C. District Court rejected WildEarth’s and PRBRC’s consolidated challenge to the IBLA decision and denied their request that the court vacate the WAII leases as well as their requested injunction against coal mining activity on the leases. On September 25, 2012 and September 26, 2012, PRBRC and WildEarth, respectively, filed notices of appeal in the United States Circuit Court of Appeals for the District of Columbia. The case is currently being briefed by the parties before the D.C. Circuit. Although both groups are appealing the decision issued by the D.C. District Court, neither group has specified what relief they are seeking from the appellate court other than for the appellate court to reverse the decision of the D.C. District Court. Antelope Coal LLC is a respondent-intervenor in the consolidated appeal. Any adverse outcome of the appeal could adversely impact or delay our ability to mine the coal subject to the leases.

Other Legal Proceedings

We are involved in other legal proceedings arising in the ordinary course of business and may become involved in additional proceedings from time to time. We believe that there are no other legal proceedings pending that are likely to have a material adverse effect on our consolidated financial condition, results of operations or cash flows. Nevertheless, we cannot predict the impact of future developments affecting our claims and lawsuits, and any resolution of a claim or lawsuit or an accrual within a particular fiscal period may adversely impact our results of operations for that period. In addition to claims and lawsuits against us, our leases by application (“LBAs”), permits, and other industry regulatory processes and approvals may also be subject to legal challenges that could adversely impact our mining operations and results.

Tax Contingencies

Our income tax calculations are based on application of the respective U.S. federal or state tax law. Our tax filings, however, are subject to audit by the respective tax authorities. Accordingly, we recognize tax benefits when it is more likely than not a position will be upheld by the tax authorities. To the extent the final tax liabilities are different from the amounts originally accrued, the increases or decreases are recorded as income tax expense or benefit.

Several audits involving our income and non-income based taxes currently are in progress. We have provided our best estimate of taxes and related interest and penalties due for potential adjustments that may result from the resolution of such tax audits. From time to time, we may engage in settlement discussions with applicable tax authorities, which may result in adjustments to our estimates of taxes and related interest and penalties.

Concentrations of Risk and Major Customers

Approximately 91% of our revenue for the six months ended June 30, 2013 was under multi-year contracts compared to 88% for the six months ended June 30, 2012. While the majority of the contracts are fixed-price, certain contracts have adjustment provisions for determining periodic price changes. For the six months ended June 30, 2013 and 2012, there was no single customer that represented more than 10% of consolidated revenue. We generally do not require collateral or other security on accounts receivable because our customers are comprised primarily of investment grade electric utilities. We seek to mitigate credit risk through credit approvals and monitoring procedures.

Guarantees and Off-Balance Sheet Risk

In the normal course of business, we are party to guarantees and financial instruments with off-balance sheet risk, such as bank letters of credit, performance or surety bonds and indemnities, which are not reflected on the consolidated balance sheet. In our past experience, virtually no claims have been made against these financial instruments. Management does not expect any material losses to result from these guarantees or off-balance-sheet instruments.

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

U.S. federal and state laws require we secure certain of our obligations to reclaim lands used for mining and to secure coal lease obligations. The primary method we have used to meet these reclamation obligations and to secure coal lease obligations is to provide a third-party surety bond, typically through an insurance company, or provide a letter of credit, typically through a bank. Specific bond and/or letter of credit amounts may change over time, depending on the activity at the respective site and any specific requirements under federal or state laws. As of June 30, 2013, we had no standby letters of credit and $647.5 million of performance bonds outstanding (including our proportional share of the Decker mine) to secure certain of our obligations to reclaim lands used for mining and to secure coal lease obligations.

10. Postretirement Medical Plan

We maintain an unfunded postretirement medical plan to provide certain postretirement medical benefits to eligible employees. Net periodic postretirement benefit costs included the following components (in thousands):

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2013		2012		2013		2012
Service Cost	$	1,238	$	1,053	$	2,475	$	2,106
Interest Cost	418		356		837		712
Amortization of prior service cost	444		394		888		788
Net periodic benefit cost	$	2,100	$	1,803	$	4,200	$	3,606

11. Related Party Transactions

Related party activity consists of coal sales to our 50% owned coal marketing company and equity method investment, Venture Fuels Partnership (in thousands):

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2013		2012		2013		2012
Sales of coal to Venture Fuels Partnership	$	4,906	$	3,503	$	5,076	$	4,690

12. Accumulated Other Comprehensive Income (Loss)

The changes in Accumulated Other Comprehensive Income (Loss) (“AOCI”) by component, net of tax are as follows (in thousands):

	Six Months Ended June 30,
	2013									2012
	Post- retirement Medical Plan			Decker Defined Benefit Pension			Total			Post- retirement Medical Plan			Decker Defined Benefit Pension			Total
Beginning balance, January 1	$	(14,684	)	$	(5,777	)	$	(20,461	)	$	(12,707	)	$	(5,907	)	$	(18,614	)
Other comprehensive income before reclassifications	19			—			19			—			58			58
Amounts reclassified from accumulated other comprehensive income	569			—			569			504			—			504
Net current period other comprehensive income	588			—			588			504			58			562
Ending balance, June 30	$	(14,096	)	$	(5,777	)	$	(19,873	)	$	(12,203	)	$	(5,849	)	$	(18,052	)

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

The reclassifications out of AOCI are as follows (in thousands):

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2013			2012			2013			2012
Postretirement Medical Plan(1)
Amortization of prior service costs included in cost of product sold(2)	$	371		$	331		$	741		$	663
Amortization of prior service costs included in selling, general and administrative expenses(2)	73			63			147			125
Total before tax	444			394			888			788
Tax benefit	(160		)	(142		)	(319		)	(284		)
Amounts reclassified from accumulated other comprehensive income	$	284		$	252		$	569		$	504

(1) See Note 10 for the computation of net periodic postretirement benefit costs.

(2) Presented on the consolidated statements of operations and comprehensive income.

13. Earnings per Share (CPE Inc. only)

Dilutive potential shares of common stock may include restricted stock and units, options and performance units issued under our Long Term Incentive Plan (“LTIP”). We apply the treasury stock method to determine dilution from restricted stock and units, options, and performance units.

The following table summarizes the calculation of diluted earnings per share (in thousands, except per share amounts):

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2013		2012		2013		2012
Numerator for calculation of diluted earnings per share:
Net income	$	4,709	$	33,678	$	20,104	$	60,296
Denominator for basic income per share — weighted-average shares outstanding	60,629		60,015		60,619		60,011
Dilutive effect of stock equivalents	536		855		504		815
Denominator for diluted earnings per share	61,165		60,870		61,123		60,826
Diluted earnings per share	$	0.08	$	0.55	$	0.33	$	0.99

For the periods presented, the following items were excluded from the diluted earnings per share calculation because they were anti-dilutive (in thousands):

	Three Months Ended		Six Months Ended
	June 30,		June 30,
	2013	2012	2013	2012
Restricted stock and units	—	6	36	110
Options outstanding	68	—	98	—
Employee stock purchase plan	—	7	56	3

14. Segment Information

We have reportable segments of Owned and Operated Mines, Logistics and Related Activities, and Corporate and Other.

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includes our Antelope mine, Cordero Rojo mine, and Spring Creek mine. Sales in this segment are primarily to domestic electric utilities; although a portion is made to our Logistics and Related Activities segment. Our mines utilize surface mining extraction processes and are all located in the PRB. The gains and losses resulting from our domestic coal futures contracts and WTI collar derivative financial instruments are reported within this segment.

Our Logistics and Related Activities segment is characterized by the services we provide to our international and domestic customers where we deliver coal to them. Services provided typically include: delivered sales contract negotiations; purchase of coal from third parties or from our owned and operated mines; coordination of the transportation and delivery of purchased coal; and sales contract administration activities. Title and risk of loss are retained by the Logistics and Related Activities segment through the transportation and delivery process. Title and risk of loss pass to the customer in accordance with the contract and typically occurs at a vessel loading terminal, a vessel unloading terminal or an end use facility. Risk associated with rail and terminal take-or-pay agreements is also borne by the Logistics and Related Activities segment. The gains and losses resulting from our international coal forward derivative financial instruments are reported within this segment.

Our Corporate and Other segment includes results relating to broker activity, our share of the Decker mine operations, and unallocated corporate costs and assets. All corporate costs, except Board of Directors related expenses, are allocated to the segments based upon their relative percentage of certain financial metrics.

Eliminations represent the purchase and sale of coal between reportable segments and the associated elimination of intercompany profit or loss in inventory. Sales between reportable segments are priced based on prevailing market prices, as determined by us with reference to independent third-party publications.

Our chief operating decision maker uses Adjusted EBITDA as the primary measure of segment reporting performance. EBITDA represents net income before (1) interest income (expense) net, (2) income tax provision, (3) depreciation and depletion, (4) amortization, and (5) accretion. Adjusted EBITDA represents EBITDA as further adjusted for 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 the updates to the tax agreement liability, including tax impacts of the IPO and Secondary Offering, (2) adjustments for derivative financial instruments, excluding fair value mark-to-market gains or losses and including cash amounts received or paid, and (3) adjustments to exclude a significant broker contract that expired in the first quarter of 2010.

Revenue

The following table presents revenue (in thousands):

	Three Months Ended						Six Months Ended
	June 30,						June 30,
	2013			2012			2013			2012
Owned and Operated Mines	$	264,975		$	265,462		$	543,749		$	568,034
Logistics and Related Activities	67,069			83,491			132,939			163,045
Corporate and Other	11,811			10,769			17,640			16,466
Eliminations of intersegment sales	(13,860		)	(16,539		)	(26,280		)	(31,459		)
Consolidated revenue	$	329,996		$	343,183		$	668,048		$	716,086

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The following table presents revenue from external customers by geographic region (in thousands):

	Three Months Ended				Six Months Ended
	June 30,				June 30,
	2013		2012		2013		2012
United States	$	264,568	$	267,602	$	545,068	$	571,630
Asia	62,522		74,491		120,074		143,153
Other	2,906		1,090		2,906		1,303
Total revenue from external customers	$	329,996	$	343,183	$	668,048	$	716,086

We attribute revenue to individual countries based on the location of the physical delivery of the coal. All of our revenue for the six months ended June 30, 2013 and 2012 originated in the U.S.

Adjusted EBITDA

The following tables reconcile segment Adjusted EBITDA to net income (in thousands):

	Three Months Ended June 30,
	2013						2012
Adjusted EBITDA
Owned and Operated Mines				$	34,230				$	51,564
Logistics and Related Activities				2,752					12,481
Corporate and Other				252					1,629
Eliminations				44					(41		)
Consolidated Adjusted EBITDA				37,277					65,632
Interest expense, net				(10,252		)			(7,624		)
Depreciation, depletion and accretion				(29,585		)			(25,707		)
Income tax				(2,462		)			(18,806		)
Tax agreement expense(1)				—					—
Derivative financial instruments:
Exclusion of fair value mark-to-market gains(2)	$	12,284					$	20,183
Inclusion of cash amounts received(3)	(2,553		)				—
Total derivative financial instruments				9,731					20,183
Expired significant broker contract				—					—

Net income				$	4,709				$	33,678

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	Six Months Ended June 30,
	2013						2012
Adjusted EBITDA
Owned and Operated Mines				$	79,892					$	118,804
Logistics and Related Activities				4,117						22,850
Corporate and Other				1,743						(98		)
Eliminations				(224		)				(181		)
Consolidated Adjusted EBITDA				85,529						141,375
Interest expense, net				(20,611		)				(13,028		)
Depreciation, depletion and accretion				(56,924		)				(51,745		)
Income tax				(11,297		)				(33,908		)
Tax agreement expense(1)				—						—
Derivative financial instruments:
Exclusion of fair value mark-to-market gains (2)	$	25,936					$	18,127
Inclusion of cash amounts received (3)	(2,529		)				(524		)
Total derivative financial instruments				23,407						17,603
Expired significant broker contract				—						—

Net income				$	20,104					$	60,296

(1) Changes to related deferred taxes are included in income tax expense.

(2) Derivative fair value mark-to-market (gains) losses reflected on the statement of operations.

(3) Derivative cash gains and losses reflected within operating cash flows.

Total Assets

The following table presents total assets (in thousands):

	June 30,			December 31,
	2013			2012
Owned and Operated Mines	$	1,793,508		$	1,826,165
Logistics and Related Activities	71,943			46,426
Corporate and Other	536,357			478,536
Eliminations	(119		)	196
Consolidated assets	$	2,401,689		$	2,351,323

As of June 30, 2013 and December 31, 2012, all of our long-lived assets were located in the U.S.

Capital Expenditures

The following table presents total capital expenditures, including investments in project development and assets acquired under capital leases (in thousands):

	Six Months Ended
	June 30,
	2013		2012
Owned and Operated Mines	$	34,325	$	18,090
Logistics and Related Activities	337		—
Corporate and Other	1,501		3,785
Eliminations	—		—
Consolidated	$	36,163	$	21,875

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

15. Equity-Based Compensation (CPE Inc. only)

The LTIP permits awards to our employees and eligible non-employee directors. The LTIP allows for the issuance of equity-based compensation in the form of restricted stock, restricted stock units, options, stock appreciation rights, dividend equivalent rights, performance awards, and share awards. Equity-based compensation expense is charged to CPE Resources through a management fee and is recorded primarily within selling, general, and administrative expenses in our consolidated statements of operations. As of June 30, 2013, unrecognized compensation cost related equity-based compensation was $13.4 million, which will be recognized over a weighted-average period of 2.1 years prior to vesting.

Restricted Stock and Restricted Stock Units

We granted restricted stock and restricted stock units under the LTIP to eligible employees and directors. Generally, the related agreements provide that full vesting will occur on the third anniversary of the grant date. However, pro-rata vesting will be sooner if a grantee terminates employment with or stops providing services to us because of death, disability, redundancy or retirement. Full vesting will occur if an employee is terminated without cause within two years after a change in control occurs (as such term is defined in the LTIP). Restricted stock units are granted to our directors and generally vest upon their resignation or retirement. They will pro-rata vest if a director resigns or retires within one year of the date of grant.

A summary of restricted stock and restricted stock unit award activity is as follows (in thousands, except per share data):

			Weighted
			Average
			Grant-Date
	Number		Fair Value
			(per share)
Non-vested shares at January 1, 2013	304		$	18.46
Granted	146		17.77
Forfeited	(2	)	17.83
Vested	(55	)	16.22
Non-vested shares at June 30, 2013	393		$	18.52

Performance-Based Share Units

The LTIP allows for the award of performance-based share units which cliff vest after three years, subject to continued employment (with accelerated vesting upon a change in control). Performance-based share units granted represent the number of shares of common stock to be awarded based on the achievement of targeted performance levels related to pre-established total stockholder return goals over a three year period and may range from 0% to 200% of the targeted amount. The grant date fair value of the awards is based upon a Monte Carlo simulation and is amortized over the performance period.

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A summary of performance-based share unit award activity is as follows (in thousands, except per share data):

			Weighted
			Average
			Grant-Date
	Number		Fair Value
			(per share)
Non-vested units at January 1, 2013	376		$	18.66
Granted	228		20.24
Forfeited	(4	)	18.85
Vested	—		—
Non-vested units at June 30, 2013	600		$	19.26

The assumptions used to estimate the fair value of the performance-based share units granted on March 11, 2013 are as follows:

Risk-free interest rate	0.4		%
Expected volatility	42.54		%
Term	3 years

Fair value (per share)	$	20.24

Non-Qualified Stock Options

Annually, we grant non-qualified stock options under the LTIP to certain employees. Generally, the agreements provide that any option awarded will become exercisable in three years. However, the option will become pro-rata exercisable sooner if a grantee terminates employment because of death, disability, redundancy or retirement. The option award will fully vest if an employee is terminated without cause within two years after a change in control occurs (as such term is defined in the LTIP). No option can be exercised more than ten years after the date of grant. Each award will be forfeited if the grantee terminates employment with or stops providing services to us for any reason other than those reasons noted above.

A summary of non-qualified stock option activity is as follows (in thousands, except per option and year amounts):

					Weighted-
			Weighted-		Average
			Average		Remaining	Aggregate
			Exercise		Contractual	Intrinsic
	Number		Price		Term	Value (1)
			(per option)		(years)
Options outstanding at January 1, 2013	1,332		$	15.95	7.38	$	4,720
Granted	229		17.50			—
Exercised	(62	)	15.00			271
Forfeited	(6	)	16.72
Options outstanding at June 30, 2013	1,494		$	16.23	7.33	$	1,313
Exercisable at June 30, 2013	931		$	15.07	6.41	$	1,313
Vested and expected to vest at June 30, 2013	1,472		$	16.21	7.31	$	1,313

(1) The intrinsic value of a stock option is the amount by which the market value of the underlying stock exceeds the exercise price of the option at period-end.

We used the Black-Scholes option pricing model to determine the fair value of stock options. Determining the fair value of equity-based awards requires judgment, including estimating the expected term that stock options will be

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NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

outstanding prior to exercise, and the associated volatility. As we have no historical exercise history, expected option life assumptions were developed using the simplified method as outlined in Topic 14, Share-Based Payment, of the Staff Accounting Bulletin Series. We utilized U.S. Treasury yields as of the grant date for our risk-free interest rate assumption, matching the treasury yield terms to the expected life of the option. We utilized a 6.5 year peer historical lookback to develop our expected volatility.

The assumptions used to estimate the fair value of options granted on March 11, 2013 are as follows:

Risk-free interest rate	1.4		%
Expected option life	6.5 years
Expected volatility	49.7		%

Fair value (per option)	$	8.72

16. Supplemental Guarantor/Non-Guarantor Financial Information (CPE Resources only)

In accordance with the indenture governing the senior notes, certain wholly-owned U.S. subsidiaries of CPE Resources (the “Guarantor Subsidiaries”) have fully and unconditionally guaranteed these senior notes on a joint and several basis. These guarantees of either series of senior notes are subject to release in the following customary circumstances:

· a sale or other disposition (including by way of consolidation or merger or otherwise) of the Guarantor Subsidiary or the sale or disposition of all or substantially all the assets of the Guarantor Subsidiary (other than to the CPE Resources or a Restricted Subsidiary (as defined in the indenture) of CPE Resources) otherwise permitted by the indenture,

· a sale of the majority of the capital stock of a Guarantor Subsidiary to a third person otherwise permitted by the indenture, after which the applicable Guarantor Subsidiary is no longer a Restricted Subsidiary,

· upon a liquidation or dissolution of a Guarantor Subsidiary so long as no default under the indenture occurs as a result thereof,

· the designation by CPE Resources in accordance with the indenture of the Guarantor Subsidiary as an Unrestricted Subsidiary or the Guarantor Subsidiary otherwise ceases to be a Restricted Subsidiary of CPE Resources in accordance with the indenture,

· defeasance or discharge of such series of senior notes or

· the release, other than the discharge through payment by the Guarantor Subsidiary, of all other guarantees by such Restricted Subsidiary of Debt (as defined in the indenture) of CPE Resources or the co-issuer of the senior notes.

Separate financial statements and other disclosures concerning the Guarantor Subsidiaries are not presented because management believes that such information is not material to the senior note holders. The following historical financial statement information is provided for the Guarantor/Non-Guarantor Subsidiaries:

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Supplemental Condensed Consolidating Statement of Operations and Comprehensive Income

(in thousands)

	Three Months Ended June 30, 2013
	Parent Company (CPE Resources)			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	324,658		$	5,338		$	—		329,996
Costs and expenses
Cost of product sold (exclusive of depreciation, depletion, amortization and accretion, shown separately)	10			275,211			6,382			—			281,603
Depreciation and depletion	627			23,953			878			—			25,459
Accretion	—			2,924			1,202			—			4,126
Derivative mark-to-market gains	—			(12,284		)	—			—			(12,284		)
Selling, general and administrative expenses	155			12,679			—			—			12,834
Other operating costs	555			636			—			—			1,191
Total costs and expenses	1,347			303,119			8,462			—			312,929
Operating income (loss)	(1,347		)	21,539			(3,124		)	—			17,067
Other income (expense)
Interest income	63			—			—			—			63
Interest expense	(9,975		)	(238		)	(102		)	—			(10,315		)
Other, net	(165		)	43			165			—			43
Total other (expense) income	(10,077		)	(195		)	63			—			(10,209		)
Income (loss) before income tax provision and earnings (losses) from unconsolidated affiliates	(11,424		)	21,344			(3,061		)	—			6,858
Income tax benefit (expense)	3,204			(6,791		)	1,124			—			(2,462		)
Earnings from unconsolidated affiliates, net of tax	5			308			—			—			313
Earnings (losses) from consolidated affiliates, net of tax	12,924			(1,937		)	—			(10,987		)	—
Net income (loss)	4,709			12,924			(1,937		)	(10,987		)	4,709
Other comprehensive income
Retiree medical plan amortization of prior service cost	444			444			—			(444		)	444
Income tax on retiree medical plan adjustments	(160		)	(160		)	—			160			(160		)
Other comprehensive income	284			284			—			(284		)	284
Total comprehensive income (loss)	$	4,993		$	13,208		$	(1,937	)	$	(11,271	)	$	4,993

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Supplemental Condensed Consolidating Statement of Operations and Comprehensive Income

(in thousands)

	Three Months Ended June 30, 2012
	Parent Company (CPE Resources)			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	337,085		$	6,098		$	—		$	343,183
Costs and expenses
Cost of product sold (exclusive of depreciation, depletion, amortization and accretion, shown separately)	(3		)	258,580			7,497			—			266,073
Depreciation and depletion	463			21,101			720			—			22,285
Accretion	—			2,330			1,092			—			3,422
Derivative mark-to-market gains	—			(20,183		)	—			—			(20,183		)
Selling, general and administrative expenses	205			12,350			—			—			12,556
Other operating costs	—			308			—			—			308
Total costs and expenses	665			274,486			9,309			—			284,461
Operating income (loss)	(665		)	62,599			(3,211		)	—			58,722
Other income (expense)
Interest income	312			—			—			—			312
Interest expense	(7,397		)	(524		)	(16		)	—			(7,936		)
Other, net	—			(110		)	—			—			(110		)
Total other expense	(7,085		)	(634		)	(16		)	—			(7,735		)
Income (loss) before income tax provision and earnings (losses) from unconsolidated affiliates	(7,750		)	61,965			(3,227		)	—			50,987
Income tax benefit (expense)	7,702			(27,654		)	1,145			—			(18,806		)
Earnings from unconsolidated affiliates, net of tax	6			1,491			—			—			1,497
Earnings (losses) from consolidated affiliates, net of tax	33,720			(2,082		)	—			(31,638		)	—
Net income (loss)	33,678			33,720			(2,082		)	(31,638		)	33,678
Other comprehensive income
Retiree medical plan amortization of prior service cost	394			394			—			(394		)	394
Other postretirement plan adjustments	—			—			—			—			—
Income tax on retiree medical plan adjustments	(142		)	(142		)	—			142			(142		)
Other comprehensive income	252			252			—			(252		)	252
Total comprehensive income (loss)	$	33,930		$	33,972		$	(2,082	)	$	(31,890	)	$	33,930

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Supplemental Condensed Consolidating Statement of Operations and Comprehensive Income

(in thousands)

	Six Months Ended June 30, 2013
	Parent Company (CPE Resources)			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	1		$	660,223		$	7,824		$	—		668,048
Costs and expenses
Cost of product sold (exclusive of depreciation, depletion, amortization and accretion, shown separately)	19			547,666			9,947			—			557,631
Depreciation and depletion	1,280			47,201			190			—			48,671
Accretion	—			5,862			2,391			—			8,253
Derivative mark-to-market gains	—			(25,936		)	—			—			(25,936		)
Selling, general and administrative expenses	420			26,022			—			—			26,442
Other operating costs	554			747			—			—			1,301
Total costs and expenses	2,273			601,562			12,528			—			616,362
Operating income (loss)	(2,272		)	58,661			(4,704		)	—			51,686
Other income (expense)
Interest income	188			—			—			—			188
Interest expense	(20,123		)	(514		)	(162		)	—			(20,799		)
Other, net	(323		)	(240		)	365			—			(198		)
Total other (expense) income	(20,258		)	(754		)	203			—			(20,809		)
Income (loss) before income tax provision and earnings (losses) from unconsolidated affiliates	(22,530		)	57,907			(4,501		)	—			30,877
Income tax benefit (expense)	4,205			(17,108		)	1,607			—			(11,297		)
Earnings from unconsolidated affiliates, net of tax	9			515			—			—			524
Earnings (losses) from consolidated affiliates, net of tax	38,420			(2,894		)	—			(35,526		)	—
Net income (loss)	20,104			38,420			(2,894		)	(35,526		)	20,104
Other comprehensive income
Retiree medical plan amortization of prior service cost	888			888			—			(888		)	888
Other postretirement plan adjustments	30			30			—			(30		)	30
Income tax on retiree medical plan adjustments	(330		)	(330		)	—			330			(330		)
Other comprehensive income	588			588			—			(588		)	588
Total comprehensive income (loss)	$	20,692		$	39,008		$	(2,894	)	$	(36,114	)	$	20,692

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Supplemental Condensed Consolidating Statement of Operations and Comprehensive Income

(in thousands)

	Six Months Ended June 30, 2012
	Parent Company (CPE Resources)			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Revenues	$	—		$	706,313		$	9,773		$	—		$	716,086
Costs and expenses
Cost of product sold (exclusive of depreciation, depletion, amortization and accretion, shown separately)	3			535,398			13,617			—			549,018
Depreciation and depletion	1,020			42,745			1,910			—			45,675
Accretion	—			4,660			1,411			—			6,070
Derivative mark-to-market gains	—			(18,127		)	—			—			(18,127		)
Selling, general and administrative expenses	419			26,878			—			—			27,298
Other operating costs	—			401			—			—			401
Total costs and expenses	1,442			591,955			16,938			—			610,335
Operating income (loss)	(1,442		)	114,358			(7,165		)	—			105,751
Other income (expense)
Interest income	758			—			—			—			758
Interest expense	(13,062		)	(692		)	(32		)	—			(13,786		)
Other, net	—			(53		)	—			—			(53		)
Total other expense	(12,304		)	(745		)	(32		)	—			(13,081		)
Income (loss) before income tax provision and earnings (losses) from unconsolidated affiliates	(13,746		)	113,613			(7,198		)	—			92,670
Income tax benefit (expense)	14,852			(51,320		)	2,560			—			(33,908		)
Earnings from unconsolidated affiliates, net of tax	12			1,522			—			—			1,534
Earnings (losses) from consolidated affiliates, net of tax	59,178			(4,638		)	—			(54,540		)	—
Net income (loss)	60,296			59,177			(4,638		)	(54,539		)	60,296
Other comprehensive income
Retiree medical plan amortization of prior service cost	788			788			—			(788		)	788
Other postretirement plan adjustments	90			90			90			(180		)	90
Income tax on retiree medical plan adjustments	(316		)	(316		)	(32		)	348			(316		)
Other comprehensive income	562			562			58			(620		)	562
Total comprehensive income (loss)	$	60,858		$	59,739		$	(4,580	)	$	(55,159	)	$	60,858

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CLOUD PEAK ENERGY INC. AND

CLOUD PEAK ENERGY RESOURCES LLC

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Supplemental Condensed Consolidating Balance Sheet

(in thousands)

	June 30, 2013
	Parent Company (CPE Resources)		Guarantor Subsidiaries		Non- Guarantor Subsidiaries			Eliminations			Consolidated
ASSETS
Current assets
Cash and cash equivalents	$	198,394	$	208	$	1,145		$	—		$	199,747
Investments in marketable securities	80,501		—		—			—			80,501
Accounts receivable	—		17,392		78,494			—			95,886
Due from related parties	—		492,762		—			(491,926		)	836
Inventories, net	5,880		72,658		4,121			—			82,659
Deferred income taxes	—		19,550		—			(27		)	19,523
Derivative financial instruments	—		37,252		—			—			37,252
Other assets	—		21,183		150			—			21,333
Total current assets	284,775		661,005		83,910			(491,953		)	537,737
Noncurrent assets
Property, plant and equipment, net	9,458		1,667,437		2,836			—			1,679,731
Goodwill	—		35,634		—			—			35,634
Deferred income taxes	27,143		11,711		18,116			—			56,970
Other assets	1,732,560		—		—			(1,688,350		)	44,210
Total assets	$	2,053,936	$	2,375,787	$	104,862		$	(2,180,303	)	$	2,354,282

LIABILITIES AND MEMBER’S EQUITY
Current liabilities
Accounts payable	$	3,004	$	56,383	$	3,310		$	—		$	62,697
Royalties and production taxes	—		127,725		1,742			—			129,467
Accrued expenses	2,101		49,178		5,380			—			56,659
Due to related parties	432,105		—		66,120			(491,926		)	6,299
Current deferred income taxes	27		—		—			(27		)	—
Current portion of federal coal lease obligations	—		54,339		—			—			54,339
Other liabilities	51		2,837		966			—			3,854
Total current liabilities	437,288		290,462		77,518			(491,953		)	313,315
Noncurrent liabilities
Senior notes	596,735		—		—			—			596,735
Federal coal lease obligations, net of current portion	—		122,928		—			—			122,928
Asset retirement obligations, net of current portion	—		167,884		71,691			—			239,576
Other liabilities	31		79,134		5,899			(23,217		)	61,846
Total liabilities	1,034,054		660,408		155,108			(515,170		)	1,334,400
Commitments and Contingencies (Note 9)
Total member’s equity	1,019,882		1,715,379		(50,246		)	(1,665,133		)	1,019,882
Total liabilities and member’s equity	$	2,053,936	$	2,375,787	$	104,862		$	(2,180,303	)	$	2,354,282

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CLOUD PEAK ENERGY INC. AND

CLOUD PEAK ENERGY RESOURCES LLC

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Supplemental Condensed Consolidating Balance Sheet

(in thousands)

	December 31, 2012
	Parent Company (CPE Resources)		Guarantor Subsidiaries		Non- Guarantor Subsidiaries			Eliminations			Consolidated
ASSETS
Current assets
Cash and cash equivalents	$	195,076	$	—	$	2,615		$	—		$	197,691
Investments in marketable securities	80,341		—		—			—			80,341
Accounts receivable	—		74,008		2,108			—			76,117
Due from related parties	—		385,102		42			(383,582		)	1,561
Inventories, net	6,741		71,312		3,622			—			81,675
Deferred income taxes	—		21,124		—			(28		)	21,096
Derivative financial instruments	138		13,647		—			—			13,785
Other assets	7		16,100		117			—			16,224
Total current assets	282,303		581,293		8,504			(383,610		)	488,490
Noncurrent assets
Property, plant and equipment, net	9,239		1,666,020		3,035			—			1,678,294
Goodwill	—		35,634		—			—			35,634
Deferred income taxes	22,807		24,650		18,679			—			66,136
Other assets	1,682,267		—		4,470			(1,646,259		)	40,478
Total assets	$	1,996,616	$	2,307,597	$	34,688		$	(2,029,869	)	$	2,309,032

LIABILITIES AND MEMBER’S EQUITY
Current liabilities
Accounts payable	$	2,558	$	45,896	$	1,117		$	—		$	49,571
Royalties and production taxes	—		126,726		2,625			—			129,351
Accrued expenses	2,087		41,529		292			—			43,908
Due to related parties	396,137		—		—			(383,583		)	12,554
Current deferred income taxes	27		—		—			(27		)	—
Current portion of federal coal lease obligations	—		63,191		—			—			63,191
Other liabilities	49		1,754		966			—			2,769
Total current liabilities	400,858		279,096		5,001			(383,611		)	301,344
Noncurrent liabilities
Senior notes	596,506		—		—			—			596,506
Federal coal lease obligations, net of current portion	—		122,928		—			—			122,928
Asset retirement obligations, net of current portion	—		164,626		74,365			—			238,991
Other liabilities	61		77,655		5,806			(33,449		)	50,073
Total liabilities	997,425		644,305		85,172			(417,060		)	1,309,842
Commitments and Contingencies (Note 9)
Total member’s equity	999,190		1,663,293		(50,484		)	(1,612,809		)	999,190
Total liabilities and member’s equity	$	1,996,615	$	2,307,598	$	34,688		$	(2,029,869	)	$	2,309,032

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CLOUD PEAK ENERGY INC. AND

CLOUD PEAK ENERGY RESOURCES LLC

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Supplemental Condensed Consolidating Statement of Cash Flows

(in thousands)

	Six Months Ended June 30, 2013
	Parent Company (CPE Resources)			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Net cash provided by (used in) operating activities	$	4,977		$	48,408		$	(9,068	)	$	—		$	44,317

Investing activities
Purchases of property, plant and equipment	(1,499		)	(22,974		)	(2		)	—			(24,475		)
Cash paid for capitalized interest	—			(8,263		)	—			—			(8,263		)
Investments in marketable securities	(32,961		)	—			—			—			(32,961		)
Maturity and redemption of investments	32,801			—			—			—			32,801
Investment in project development	—			(4,087		)	—			—			(4,087		)
Return of partnership escrow deposit	—			—			4,468			—			4,468
Contributions made to subsidiary	—			(7,600		)	—			7,600			—
Distribution received from subsidiary	—			4,468			—			(4,468		)	—
Other	—			63			—			—			63
Net cash provided by (used in) investing activities	(1,659		)	(38,393		)	4,466			3,132			(32,454		)

Financing activities
Principal payments of federal coal leases	—			(8,852		)	—			—			(8,852		)
Contributions received from parent	—			—			7,600			(7,600		)	—
Distributions made to parent	—			—			(4,468		)	4,468			—
Other	—			(955		)	—			—			(955		)
Net cash provided by (used in) financing activities	—			(9,807		)	3,132			(3,132		)	(9,807		)

Net increase (decrease) in cash and cash equivalents	3,318			208			(1,470		)	—			2,056
Cash and cash equivalents at beginning of year	195,076			—			2,615			—			197,691
Cash and cash equivalents at the end of year	$	198,394		$	208		$	1,145		$	—		$	199,747

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CLOUD PEAK ENERGY INC. AND

CLOUD PEAK ENERGY RESOURCES LLC

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Supplemental Condensed Consolidating Statement of Cash Flows

(in thousands)

	Six Months Ended June 30, 2012
	Parent Company (CPE Resources)			Guarantor Subsidiaries			Non- Guarantor Subsidiaries			Eliminations			Consolidated
Net cash provided by (used in) operating activities	$	(24,221	)	$	112,270		$	(6,768	)	$	—		$	81,282

Investing activities
Acquisition of Youngs Creek and CX Ranch coal and land assets	—			(300,259		)	—			—			(300,259		)
Purchases of property, plant and equipment	(3,755		)	(18,090		)	(30		)	—			(21,875		)
Cash paid for capitalized interest	—			(36,477		)	—			—			(36,477		)
Investments in marketable securities	(53,854		)	—			—			—			(53,854		)
Maturity and redemption of investments	28,887			—			—			—			28,887
Return of restricted cash	71,244			—			—			—			71,244
Partnership escrow deposit	—			—			(4,470		)	—			(4,470		)
Contributions made to subsidiary	(300,259		)	(10,570		)	—			310,829			—
Other	—			1,825			—			—			1,825
Net cash provided by (used in) investing activities	(257,736		)	(363,571		)	(4,501		)	310,829			(314,979		)

Financing activities
Principal payments of federal coal leases	—			(48,959		)	—			—			(48,959		)
Contributions received from parent	—			300,259			10,570			(310,829		)	—
Net cash provided by (used in) financing activities	—			251,300			10,570			(310,829		)	(48,959		)

Net increase (decrease) in cash and cash equivalents	(281,957		)	—			(699		)	—			(282,656		)
Cash and cash equivalents at beginning of year	401,087			2			3,151			—			404,240
Cash and cash equivalents at the end of year	$	119,131		$	2		$	2,451		$	—		$	121,584

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CAUTIONARY NOTICE REGARDING FORWARD-LOOKING STATEMENTS

This report contains forward-looking statements that involve substantial risks and uncertainties. You can identify these statements by forward-looking words such as “anticipate,” “believe,” “could,” “estimate,” “expect,” “intend,” “may,” “plan,” “potential,” “should,” “will,” “would,” or similar words. You should read statements that contain these words carefully because they discuss our current plans, strategies, prospects, and expectations concerning our business, operating results, financial condition, and other similar matters. While we believe that these forward-looking statements are reasonable as and when made, there may be events in the future that we are not able to predict accurately or control, and there can be no assurance that future developments affecting our business will be those that we anticipate. Additionally, all statements concerning our expectations regarding future operating results are based on current forecasts for our existing operations and do not include the potential impact of any future acquisitions. The factors listed under “Risk Factors” in our Annual Report on Form 10-K for the year ended December 31, 2012 (our “2012 Form 10-K”), as well as any cautionary language in this report, describe the known material risks, uncertainties and events that may cause our actual results to differ materially from the expectations we describe in our forward-looking statements. Additional factors or events 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. You are cautioned not to place undue reliance on the forward-looking statements contained herein. We undertake no obligation to update or revise publicly any forward-looking statements, whether as a result of new information, future events, or otherwise, except as required by law. The following factors are among those that may cause actual results to differ materially and adversely from our forward-looking statements:

· the prices we receive for our coal and our ability to effectively execute our forward sales strategy;

· competition with other producers of coal;

· competition with natural gas and other non-coal energy resources, which may be increased as a result of energy policies, regulations and subsidies or other government incentives that encourage or mandate use of alternative energy sources;

· coal-fired power plant capacity, including the impact of environmental regulations, energy policies and other factors that may cause electric utilities to phase out or close existing coal-fired power plants or reduce construction of any new coal-fired power plants;

· market demand for domestic and foreign coal, electricity and steel;

· our ability to maintain and grow our export sales;

· railroad, export terminal and other transportation performance, costs and availability, including development of additional export terminal capacity and our ability to access additional capacity on commercially reasonable terms;

· domestic and international economic conditions;

· timing of reductions or increases in customer coal inventories;

· weather conditions or weather-related damage that impacts demand for coal, our mining operations, our customers or transportation infrastructure;

· risks inherent to surface coal mining;

· our ability to successfully acquire coal and appropriate land access rights at attractive prices and in a timely manner and our ability to effectively resolve issues with conflicting mineral development that may impact our mine plans;

· our ability to produce coal at existing and planned volumes and to effectively manage the costs of our operations;

· our plans and objectives for future operations and the development of additional coal reserves, including risks associated with acquisitions;

· the impact of current and future environmental, health, safety and other laws, regulations, treaties or governmental policies, or changes in interpretations thereof, and third-party regulatory challenges, including those affecting our coal mining operations or our customers’ coal usage, carbon and other gaseous emissions or ash handling, or the logistics, transportation, or terminal industries, as well as related costs and liabilities;

· the impact of required regulatory processes and approvals to lease and obtain permits for coal mining operations or to transport coal to domestic and foreign customers, including third-party legal challenges;

· any increases in rates or changes in regulatory interpretations or assessment methodologies with respect to royalties or severance and production taxes;

· inaccurately estimating the costs or timing of our reclamation and mine closure obligations;

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· disruptions in delivery or increases in pricing from third-party vendors of raw materials and other consumables which are necessary for our operations, such as explosives, petroleum-based fuel, tires, steel, and rubber;

· our assumptions concerning coal reserve estimates;

· our relationships with, and other conditions affecting, our customers and other counterparties, including economic conditions and the credit performance and credit risks associated with our customers and other counterparties, such as lenders under our credit agreement and financial institutions with whom we maintain accounts or enter hedging arrangements;

· the results of our hedging strategies for commodities, including our current hedging programs for coal sales and diesel fuel costs;

· the terms and restrictions of our indebtedness;

· liquidity constraints, including those resulting from the cost or unavailability of financing due to credit market conditions or our compliance with the financial covenants in our debt agreements;

· our assumptions regarding payments arising under the Tax Receivable Agreement and other agreements related to the initial public offering of Cloud Peak Energy Inc.;

· our liquidity, results of operations, and financial condition generally, including amounts of working capital that are available; and

· other factors, including those discussed in Item 1A of our 2012 Form 10-K.

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Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations.

Explanatory Note

Cloud Peak Energy Resources LLC (“CPE Resources”) is the sole direct subsidiary of Cloud Peak Energy Inc. (“CPE Inc.”), providing 100% of CPE Inc.’s total consolidated revenue for the three and six months ended June 30, 2013 and constituting nearly 100% of CPE Inc.’s total consolidated assets as of June 30, 2013.

Unless the context indicates otherwise, the terms “Cloud Peak Energy,” the “Company,” “we,” “us,” and “our” refer to both CPE Inc. and CPE Resources and their subsidiaries. Discussions or areas of this report that either apply only to CPE Inc. or CPE Resources are clearly noted in such sections.

This Item 2 may contain forward-looking statements that involve substantial risks and uncertainties. When considering these forward-looking statements you should keep in mind the cautionary statements in this report and our other Securities and Exchange Commission (“SEC”) filings, including Risk Factors in Item 1A of our Annual Report on Form 10-K for the year ended December 31, 2012 (“2012 Form 10-K”). Please see “Cautionary Notice Regarding Forward-Looking Statements” elsewhere in this document.

This Item 2 is intended to help the reader understand our results of operations and financial condition. This discussion should be read in conjunction with our unaudited condensed consolidated financial statements in Item 1 of this report and our other SEC filings, including our audited consolidated financial statements in Item 8 of our 2012 Form 10-K.

Overview

We currently operate solely in the PRB, the lowest cost region of the major coal producing regions in the U.S, where we operate three wholly-owned surface coal mines, the Antelope mine, the Cordero Rojo mine and the Spring Creek mine. We also have two major development projects, the Youngs Creek project and the Crow project. We also own a 50% non-operating interest in the Decker mine, which we have contracted to sell to the other 50% owner, see Note 9 to our notes to unaudited condensed consolidated financial statements in Item 1.

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ultimate capacity of the terminal and is subject to the terms of the option agreement. The terminal would accommodate cape size vessels. Our option is exercisable following future permit completion for the terminal, the timing of which is uncertain.

Segment Information

We have reportable segments of Owned and Operated Mines, Logistics and Related Activities, and Corporate and Other.

Our Owned and Operated Mines segment is characterized by the predominant focus on thermal coal production where the sale occurs at the mine site and where title and risk of loss pass to the customer at that point. This segment includes our Antelope mine, Cordero Rojo mine, and Spring Creek mine. Sales in this segment are primarily to domestic electric utilities; although a portion is made to our Logistics and Related Activities segment. Our mines utilize surface mining extraction processes and are all located in the PRB. The gains and losses resulting from our domestic coal futures contracts and WTI collar derivative financial instruments are reported within this segment.

Our Logistics and Related Activities segment is characterized by the services we provide to our international and domestic customers where we deliver coal to them. Services provided typically include: delivered sales contract negotiations; purchase of coal from third parties or from our owned and operated mines; coordination of the transportation and delivery of purchased coal; and sales contract administration activities. Title and risk of loss are retained by the Logistics and Related Activities segment through the transportation and delivery process. Title and risk of loss pass to the customer in accordance with the contract and typically occur at a vessel loading terminal, a vessel unloading terminal or an end use facility. Risk associated with rail and terminal take-or-pay agreements is also borne by the Logistics and Related Activities segment. The gains and losses resulting from our international coal forward derivative financial instruments are reported within this segment.

Core Business Operations

Our key business drivers include the following:

· the volume of coal sold from our owned and operated mines;

· the price for which we sell our coal;

· the costs of mining, including labor, repairs and maintenance, fuel, explosives, depreciation of capital equipment, and depletion of coal leases;

· capital expenditures to acquire property, plant and equipment;

· the volume of deliveries coordinated by our Logistics and Related Activities segment to customer contracted destinations;

· the costs for logistics services, rail, and port charges for coal sales made on a delivered basis; and

· the results of our coal forward and futures contracts.

The volume of coal that we sell in any given year is driven by international and domestic demand for coal-generated electric power. Demand for coal-generated electric power may be affected by many factors including weather patterns, natural gas prices, coal-fired generating capacity and utilization, environmental and legal challenges, political and regulatory factors, energy policies, international and domestic economic conditions, and other factors discussed in this Item 2 and in our 2012 Form 10-K.

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The price at which we sell our coal is a function of the demand relative to the supply for coal. We typically enter into multi-year contracts with our customers which helps mitigate the risks associated with any short-term imbalance in supply and demand. We typically seek to enter each year with expected production effectively fully sold. This strategy helps us run our mines at predictable production rates, which helps us control operating costs.

As is common in the PRB, coal seams at our existing mines naturally deepen, resulting in additional overburden to be removed at additional cost. In line with the worldwide mining industry, we have experienced increased operating costs for mining equipment, diesel fuel and supplies, and employee wages and salaries. We use costless collars to help manage certain exposures to diesel fuel prices.

We incur significant capital expenditures to maintain, update and expand our mining equipment, surface land holdings and coal reserves. In line with the worldwide mining industry trends, the cost of capital equipment is generally increasing. In addition, as the costs of acquiring federal coal leases and associated surface rights increase, our depletion costs also increase.

The volume of coal sold on a delivered basis is influenced by international and domestic market conditions. Domestic demand for coal sold on a delivered basis is currently flat while international demand remains robust, enabling us to compete for international coal sales during the past few years. Our ability to increase our international coal sales volumes is currently limited by available port capacity.

Coal sold on a delivered basis to customer contracted destinations, including sales to Asian customers, involves us arranging and paying for logistics services, which can include rail, rail car hire, and port charges including any demurrage incurred and other costs. These logistics costs are affected by volume, various scheduling considerations, and negotiated rates for rail and port services. We are also incurring costs to investigate and pursue development of additional port opportunities.

We entered into coal forward and futures contracts that are scheduled to settle at various dates between 2013 and 2016 to manage a portion of our export and domestic coal sales prices.

Current Considerations

Owned and Operated Mines Segment

The domestic environment has shown signs of improvement during the three months ended June 30, 2013 with recovering coal burn and decreasing PRB coal stockpiles. In addition, natural gas prices have remained at a level where most plants consuming PRB coal are economically able to dispatch coal. However, PRB forward prices have remained low. There has been a significant increase in electric utilities contracting during the three months ended June 30, 2013 with many customers looking to rebuild their forward contracted positions after letting them decline significantly last year. So far the increased contracting has not overcome the capacity overhang created by last year’s decreased demand. We are optimistic that the steady coal burn and continued reduction in PRB inventories will lead to prices moving higher later in the year. Revenue for our Owned and Operated Mines segment are expected to be relatively flat compared to 2012 as volumes and realized prices are not expected to change significantly.

Shipments for the three months ended June 30, 2013 were hindered primarily due to weather interruptions, unplanned power plant outages at a small number of major customers, and the impact of production interruptions during maintenance downtime. Assuming there is normal summer weather, we anticipate shipments will pick up in the second half of 2013, benefiting our costs per ton and quarterly Adjusted EBITDA for the Owned and Operated Mines segment.

We are focused on managing cash flow, capital expenditures, and cost containment under current market conditions. We are reducing our full year anticipated capital expenditures to a new range of $60 million to $70 million, a reduction of the mid-point of $15 million from previous guidance. We are also evaluating future capital investments that would be necessary to maintain current production rates. If depressed forward markets do not improve, we are currently evaluating reducing shipments at our 8400 Btu Cordero Rojo mine by around 10 million tons per year starting in 2015. Consequently, we currently are reducing our forward contracting of 8400 Btu coal from 2015.

Logistics and Related Activities Segment

We are increasing our expected shipments through the Westshore terminal to be approximately 5 million tons to international customers from our Logistics and Related Activities segment in 2013. This increase is due to additional

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throughput for the remainder of this year and we have priced or indexed settled the remaining volume. The low international coal prices mean our planned export shipments for the remainder of 2013 will have minimal logistics margin but continue to provide economic return to our consolidated results. Our hedging program mitigated some of this impact, with a realized gain of $2.6 million in the three months ended June 30, 2013.

Environmental and Other Regulatory Matters

Federal, state and local authorities regulate the U.S. coal mining industry with respect to various matters, including air quality standards, water pollution, plant and wildlife protection, the discharge of materials into the environment and the effects of mining on surface and groundwater quality and availability. These laws and regulations have had, and will continue to have, a significant effect on our production costs and our competitive position. Future laws, regulations or orders, including those relating to global climate change, may cause coal to become a less attractive fuel source, thereby reducing coal’s share of the market for fuels and other energy sources used to generate electricity. See Part I—Item I. Business “Environmental and Other Regulatory Matters” in our 2012 Form 10-K.

Adjusted EBITDA and Adjusted EPS (CPE Inc. only)

EBITDA, Adjusted EBITDA and Adjusted EPS are intended to provide additional information only and do not have any standard meaning prescribed by generally accepted accounting principles in the U.S. (“U.S. GAAP”). A quantitative reconciliation of Adjusted EBITDA to income from continuing operations, or net income, as applicable, and Adjusted EPS to EPS (as defined below) is found in the tables below.

EBITDA represents income from continuing operations, or net income, as applicable, before (1) interest income (expense) net, (2) income tax provision, (3) depreciation and depletion, (4) amortization, and (5) accretion. Adjusted EBITDA represents EBITDA as further adjusted for 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 the updates to the tax agreement liability, including tax impacts of the IPO and Secondary Offering, (2) adjustments for derivative financial instruments, excluding fair value mark-to-market gains or losses and including cash amounts received or paid, and (3) adjustments to exclude a significant broker contract that expired in the first quarter of 2010.

Adjusted EPS represents diluted earnings (loss) per common share or diluted earnings (loss) per share attributable to controlling interest from continuing operations, as applicable (“EPS”), adjusted to exclude the estimated per share impact of the same specifically identified items used to calculate Adjusted EBITDA as described above, adjusted at the statutory rate of 36%.

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 income from continuing operations or net income. Adjusted EBITDA is also used as part of our incentive compensation program for our executive officers and others.

We believe Adjusted EBITDA and Adjusted EPS are 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. Similarly, we believe Adjusted EPS provides an appropriate measure to use in assessing our performance across periods given that this measure provides an adjustment for certain specifically identified significant items that are not considered to directly reflect our core operations, the magnitude of which may vary significantly from period to period and, thereby, have a disproportionate effect on the earnings per share reported for a given period.

Our management recognizes that using Adjusted EBITDA and Adjusted EPS as performance measures has inherent limitations as compared to income from continuing operations, net income, EPS or other U.S. GAAP financial measures, as these non-GAAP measures exclude certain items, including items that are recurring in nature, which may be meaningful to investors. Adjusted EBITDA excludes interest expense and interest income; however, as we have historically borrowed money in order to finance transactions and operations, and have invested available cash to generate interest income, interest expense and interest income are elements of our cost structure and influence our ability to generate revenue and returns for stockholders. Adjusted EBITDA excludes depreciation and depletion and amortization; however, as we use capital and

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intangible assets to generate revenue, depreciation, depletion and amortization are necessary elements of our costs and ability to generate revenue. Adjusted EBITDA also excludes accretion expense; however, as we are legally obligated to pay for costs associated with the reclamation and closure of our mine sites, the periodic accretion expense relating to these reclamation costs is a necessary element of our costs and ability to generate revenue. Adjusted EBITDA excludes income taxes; however, as we are organized as a corporation, the payment of taxes is a necessary element of our operations. Adjusted EBITDA and Adjusted EPS exclude the tax impacts of the IPO and Secondary Offering; however, this represents our current estimate of payments on the tax agreement liability that we will be required to make to Rio Tinto and changes to the realizability of our deferred tax assets based on changes in our estimated future taxable income. Adjusted EBITDA and Adjusted EPS exclude fair value mark-to-market gains or losses for derivative financial instruments; however, Adjusted EBITDA and Adjusted EPS include cash amounts received or paid on derivative financial instruments. Finally, Adjusted EBITDA and Adjusted EPS exclude income statement amounts attributable to our significant broker contract that expired in the first quarter of 2010; however, this historically represented a positive contribution to our operating results.

As a result of these exclusions, Adjusted EBITDA and Adjusted EPS should not be considered in isolation and do not purport to be alternatives to income from continuing operations, net income, EPS or other U.S. GAAP financial measures as a measure of our operating performance.

When using Adjusted EBITDA as a performance measure, management intends to compensate for these limitations by comparing it to income from continuing operations or net income in each period, so as to allow for the comparison of the performance of the underlying core operations with the overall performance of the company on a full-cost, after-tax basis. Using Adjusted EBITDA and income from continuing operations or net income to evaluate the business assists management and investors in (a) assessing our relative performance against our competitors and (b) ultimately monitoring our capacity to generate returns for stockholders.

Because not all companies use identical calculations, our presentations of Adjusted EBITDA and Adjusted EPS may not be comparable to other similarly titled measures of other companies. Moreover, our presentation of Adjusted EBITDA is different than EBITDA as defined in our debt financing agreements.

A quantitative reconciliation for each of the periods presented of net income to Adjusted EBITDA and EPS to Adjusted EPS is found within this Item 2.

Three Months Ended June 30, 2013 Compared to Three Months Ended June 30, 2012

Summary

The following table summarizes key results (in millions):

	Three Months Ended
	June 30,					Change
	2013			2012		Amount			Percent
Total tons sold	20.9			20.7		0.2			0.9
Total revenue	$	330.0		$	343.2	$	(13.2	)	(3.8	)
Net income	4.7			33.7		(29.0		)	(86.1	)
Adjusted EBITDA(1)	37.3			65.6		(28.3		)	(43.1	)
Adjusted EPS(1)	$	(0.02	)	$	0.34	$	(0.36	)	(105.9	)

(1) Non-GAAP measure; please see definition above and reconciliation below.

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Adjusted EBITDA and Adjusted EPS (CPE Inc. only)

The following tables present a reconciliation of net income to Adjusted EBITDA, diluted earnings per common share to Adjusted EPS, and segment Adjusted EBITDA to net income (in millions, except per share amounts):

Adjusted EBITDA

	Three Months Ended
	June 30,
	2013						2012
Net income				$	4.7					$	33.7
Interest income				(0.1		)				(0.3		)
Interest expense				10.3						7.9
Income tax expense				2.5						18.8
Depreciation and depletion				25.5						22.3
Accretion				4.1						3.4
EBITDA				47.0						85.8
Tax agreement benefit(1)				—						—
Derivative financial instruments:
Exclusion of fair value mark-to-market gains(2)	$	(12.3	)				$	(20.2	)
Inclusion of cash amounts received (paid)(3)	2.6						—
Total derivative financial instruments				(9.7		)				(20.2		)
Expired significant broker contract				—						—
Adjusted EBITDA				$	37.3					$	65.6

(1) Changes to related deferred taxes are included in income tax expense.

(2) Derivative fair value mark-to-market (gains) losses reflected on the statement of operations.

(3) Derivative cash gains and losses reflected within operating cash flows.

Adjusted EPS

	Three Months Ended
	June 30,
	2013						2012
Diluted earnings per common share				$	0.08					$	0.55
Tax agreement expense including tax impacts of IPO and Secondary Offering				—						—
Derivative financial instruments:
Exclusion of fair value mark-to-market gains	$	(0.13	)				$	(0.21	)
Inclusion of cash amounts received (paid)	0.03						—
Total derivative financial instruments				(0.10		)				(0.21		)
Expired significant broker contract				—						—
Adjusted EPS				$	(0.02	)				$	0.34
Weighted-average dilutive shares outstanding (in millions)				61.2						60.9

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Adjusted EBITDA by Segment

	Three Months Ended
	June 30,
	2013						2012
Owned and Operated Mines
Adjusted EBITDA				$	34.2				$	51.6
Depreciation and depletion				(23.9		)			(21.1		)
Accretion				(2.8		)			(2.2		)
Derivative financial instruments:
Exclusion of fair value mark-to-market gains (losses)	$	(0.1	)				$	0.1
Inclusion of cash amounts (received) paid	0.1						—
Total derivative financial instruments				—					0.1
Other				(0.1		)			—
Operating income				7.4					28.4

Logistics and Related Activities
Adjusted EBITDA				2.8					12.5
Derivative financial instruments:
Exclusion of fair value mark-to-market gains	12.4						20.1
Inclusion of cash amounts (received) paid	(2.6		)				—
Total derivative financial instruments				9.8					20.1
Operating income				12.5					32.6

Corporate and Other
Adjusted EBITDA				0.2					1.6
Depreciation and depletion				(1.5		)			(1.2		)
Accretion				(1.3		)			(1.2		)
Earnings from unconsolidated affiliates, net of tax				(0.3		)			(1.5		)
Operating loss				(2.8		)			(2.3		)

Eliminations
Adjusted EBITDA				—					—
Operating income				—					—
Consolidated operating income				17.1					58.7
Interest income				0.1					0.3
Interest expense				(10.3		)			(7.9		)
Other, net				—					(0.1		)
Income tax expense				(2.5		)			(18.8		)
Earnings from unconsolidated affiliates, net of tax				0.3					1.5
Net income				$	4.7				$	33.7

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Results of Operations

Revenues

The following table presents revenues (in millions except per ton amounts):

	Three Months Ended
	June 30,						Change
	2013			2012			Amount			Percent
Owned and Operated Mines
Realized price per ton sold	$	13.05		$	13.11		$	(0.06	)	(0.5	)
Tons sold	20.1			20.1			—			—

Coal revenue	$	262.3		$	263.1		$	(0.8	)	(0.3	)
Other revenue	2.7			2.3			0.4			17.4
Logistics and Related Activities
Total tons delivered	1.4			1.3			0.1			7.7
Asian export tons	1.2			1.0			0.2			20.0

Revenue	$	67.1		$	83.5		$	(16.4	)	(19.6	)
Corporate and Other
Revenue	$	11.8		$	10.8		$	1.0		9.3
Eliminations of intersegment sales
Revenue	$	(13.9	)	$	(16.5	)	$	2.6		(15.8	)
Total Consolidated
Revenue	$	330.0		$	343.2		$	(13.2	)	(3.8	)

Revenue from our Owned and Operated Mines segment remained relatively flat for the three months ended June 30, 2013 compared to 2012. Spot prices were lower for indexed tons sold as a result of the lower demand for PRB coal while domestic electric utility customers continue to normalize their stockpiles. Other revenue consists primarily of dust suppressant additives billed to our customers.

Revenue from our Logistics and Related Activities segment decreased primarily as a result of lower prices on our Asian deliveries through the port partially offset by an increase in Asian tons delivered. Our Asian delivered sales are priced broadly in line with a number of relevant international coal indices adjusted for energy content and other quality and delivery criteria. These indices include the Newcastle benchmark price, which is significantly lower in 2013 as compared to 2012. Based on the comparative quality and transport costs, our delivered sales are generally priced at approximately 60% to 70% of the forward Newcastle price. In addition, the volume of domestic deliveries coordinated decreased in the three months ended June 30, 2013 compared to 2012.

Revenue from our Corporate and Other segment increased primarily due to additional broker tons sold partially offset by lower revenue at the Decker mine.

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Cost of Product Sold

The following table presents cost of product sold (in millions, except per ton amounts):

	Three Months Ended
	June 30,						Change
	2013			2012			Amount			Percent
Owned and Operated Mines
Average cost per ton sold	$	10.81		$	10.09		$	0.72		7.1

Cost of product sold (produced coal)	$	217.1		$	202.6		$	14.5		7.2
Other cost of product sold	2.8			2.0			0.8			40.0
Logistics and Related Activities
Cost of product sold	64.4			67.5			(3.1		)	(4.6	)
Corporate and Other
Cost of product sold	11.2			10.4			0.8			7.7
Eliminations of Intersegment Sales
Cost of product sold	(13.9		)	(16.5		)	2.6			15.8
Total Consolidated
Cost of product sold	$	281.6		$	266.1		$	15.5		5.8

The cost of product sold and average cost per ton sold for our Owned and Operated Mines segment increased primarily as a result of higher direct operating costs from production challenges related to weather interruptions, unplanned power plant outages at a small number of major customers, and the impact of production interruptions during maintenance downtime. We have also experienced cost inflation on our explosives purchases and incurred additional labor costs associated with longer hauls and increased strip ratios, particularly at our Cordero Rojo mine.

Cost of product sold for our Logistics and Related Activities segment decreased primarily due to a reduction in the volume of domestic deliveries coordinated. The higher volume of Asian deliveries through the port were coordinated at lower unit delivery costs resulting in a consistent overall cost for the comparative periods. The Asian delivered tons that were coordinated during the second quarter of 2013 were delivered through the lower cost Westshore port.

Cost of product sold for our Corporate and Other segment increased primarily due to the additional broker tons sold partially offset by lower costs at the Decker mine.

Operating Income

The following table presents operating income (in millions):

	Three Months Ended
	June 30,						Change
	2013			2012			Amount			Percent
Owned and Operated Mines
Operating income	$	7.4		$	28.4		$	(21.0	)	(73.9	)
Logistics and Related Activities
Operating income	$	12.5		$	32.6		$	(20.1	)	(61.7	)
Corporate and Other
Operating loss	$	(2.8	)	$	(2.3	)	$	(0.5	)	(21.7	)
Eliminations of Intersegment Sales
Operating income	$	—		$	—		$	—		—
Total Consolidated
Operating income	$	17.1		$	58.7		$	(41.6	)	(70.9	)

In addition to the revenue and cost of product sold factors previously discussed, operating income for our Owned and Operated Mines segment decreased due to higher depreciation and depletion and a higher allocation of selling, general and administrative costs to this segment.

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In addition to the revenue and cost of product sold factors previously discussed, operating income for our Logistics and Related Activities segment decreased due to the mark-to-market impact from our international coal forward contracts as a result of declining international coal prices. The $12.4 million gain in the three months ended June 30, 2013 was lower as compared to the $20.1 million gain in 2012.

Operating loss for our Corporate and Other segment increased primarily due to the revenue and cost of product sold factors previously discussed.

Other Expense

The following table presents other expense (in millions):

	Three Months Ended
	June 30,				Change
	2013		2012		Amount		Percent
Other expense	$	10.2	$	7.7	$	2.5	32.5

Other expense increased for the three months ended June 30, 2013 compared to 2012 as a result of higher interest expense due to a reduction in the amount of interest capitalized in the current period.

Income Tax Provision

The following table presents income tax provision (in millions):

	Three Months Ended
	June 30,						Change
	2013			2012			Amount			Percent
Income tax expense	$	2.5		$	18.8		$	(16.3	)	(86.7	)
Effective tax rate	35.9		%	36.9		%	(1.0		)	(2.7	)

Our statutory income tax rate, including state income taxes, is 36%.

Six Months Ended June 30, 2013 Compared to Six Months Ended June 30, 2012

Summary

The following table summarizes key results (in millions):

	Six Months Ended
	June 30,				Change
	2013		2012		Amount			Percent
Total tons sold	42.2		43.6		(1.4		)	(3.3	)
Total revenue	$	668.0	$	716.1	$	(48.0	)	(6.7	)
Net income	20.1		60.3		(40.2		)	(66.7	)
Adjusted EBITDA(1)	85.5		141.4		(55.9		)	(39.5	)
Adjusted EPS(1)	$	0.08	$	0.81	$	(0.72	)	(89.6	)

(1) Non-GAAP measure; please see definition in Adjusted EBITDA and Adjusted EPS section above and reconciliation below.

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Adjusted EBITDA and Adjusted EPS (CPE Inc. only)

Adjusted EBITDA

	Six Months Ended
	June 30,
	2013						2012
Net income				$	20.1					$	60.3
Interest income				(0.2		)				(0.8		)
Interest expense				20.8						13.8
Income tax expense				11.3						33.9
Depreciation and depletion				48.7						45.7
Amortization				—						—
Accretion				8.3						6.1
EBITDA				108.9						159.0
Tax agreement benefit(1)				—						—
Derivative financial instruments:
Exclusion of fair value mark-to-market gains(2)	$	(25.9	)				$	(18.1	)
Inclusion of cash amounts received(3)	2.5						0.5
Total derivative financial instruments				(23.4		)				(17.6		)
Expired significant broker contract				—						—
Adjusted EBITDA				$	85.5					$	141.4

(1) Changes to related deferred taxes are included in income tax expense.

(2) Derivative fair value mark-to-market (gains) losses reflected on the statement of operations.

(3) Derivative cash gains and losses reflected within operating cash flows.

Adjusted EPS

	Six Months Ended
	June 30,
	2013						2012
Diluted earnings per common share				$	0.33					$	0.99
Tax agreement expense including tax impacts of IPO and Secondary Offering				—						—
Derivative financial instruments:
Exclusion of fair value mark-to-market gains	$	(0.27	)				$	(0.19	)
Inclusion of cash amounts received	0.03						0.01
Total derivative financial instruments				(0.25		)				(0.19		)
Expired significant broker contract				—						—
Adjusted EPS				$	0.08					$	0.81
Weighted-average dilutive shares outstanding (in millions)				61.1						60.8

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Adjusted EBITDA by Segment

	Six Months Ended
	June 30,
	2013						2012
Owned and Operated Mines
Adjusted EBITDA				$	79.9					$	118.8
Depreciation and depletion				(47.2		)				(42.7		)
Accretion				(5.7		)				(4.5		)
Derivative financial instruments:
Exclusion of fair value mark-to-market gains (losses)	$	(0.2	)				$	0.1
Inclusion of cash amounts (received) paid	0.1						—
Total derivative financial instruments				(0.1		)				0.1
Other				0.2						—
Operating income				27.1						71.7

Logistics and Related Activities
Adjusted EBITDA				4.1						22.9
Derivative financial instruments:
Exclusion of fair value mark-to-market gains	26.2						18.1
Inclusion of cash amounts received	(2.6		)				(0.5		)
Total derivative financial instruments				23.6						17.6
Operating income				27.6						40.4

Corporate and Other
Adjusted EBITDA				1.7						—
Depreciation and depletion				(1.5		)				(2.9		)
Accretion				(2.6		)				(1.6		)
Earnings from unconsolidated affiliates, net of tax				(0.5		)				(1.5		)
Operating loss				(2.9		)				(6.2		)

Eliminations
Adjusted EBITDA				(0.2		)				(0.2		)
Operating loss				(0.2		)				(0.2		)
Consolidated operating income				51.7						105.7
Interest income				0.2						0.8
Interest expense				(20.8		)				(13.8		)
Other, net				(0.2		)				(0.1		)
Income tax expense				(11.3		)				(33.9		)
Earnings from unconsolidated affiliates, net of tax				0.5						1.5
Net income				$	20.1					$	60.3

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Revenues

The following table presents revenues (in millions except per ton amounts):

	Six Months Ended
	June 30,						Change
	2013			2012			Amount			Percent
Owned and Operated Mines
Realized price per ton sold	$	13.07		$	13.21		$	(0.14	)	(1.1	)
Tons sold	41.2			42.6			(1.4		)	(3.3	)

Coal revenue	$	537.9		$	563.2		$	(25.3	)	(4.5	)
Other revenue	5.9			4.8			1.1			22.9
Logistics and Related Activities
Total tons delivered	2.8			2.6			0.2			6.7
Asian export tons	2.4			2.0			0.4			21.0

Revenue	$	132.9		$	163.0		$	(30.1	)	(18.5	)
Corporate and Other
Revenue	$	17.6		$	16.5		$	1.1		6.7
Eliminations of intersegment sales
Revenue	$	(26.3	)	$	(31.5	)	$	5.2		(16.5	)
Total Consolidated
Revenue	$	668.0		$	716.1		$	(48.1	)	(6.7	)

The decrease in revenue from our Owned and Operated Mines segment was primarily the result of 1.4 million fewer tons of coal sold in 2013 compared to 2012, reflecting the lower demand for PRB coal while domestic electric utility customers continue to normalize their stockpiles. In addition, our realized price per ton sold in 2013 compared to 2012 decreased, reflecting the lower spot price for indexed tons sold. Other revenue consists primarily of dust suppressant additives billed to our customers.

Revenue from our Corporate and Other segment increased primarily due to additional broker tons sold partially offset by lower revenue at the Decker mine.

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Cost of Product Sold

The following table presents cost of product sold (in millions except per ton amounts):

	Six Months Ended
	June 30,						Change
	2013			2012			Amount			Percent
Owned and Operated Mines
Average cost per ton sold	$	10.58		$	9.93		$	0.66		6.6

Cost of product sold (produced coal)	$	435.6		$	423.1		$	12.5		3.0
Other cost of product sold	5.4			4.9			0.5			10.2
Logistics and Related Activities
Cost of product sold	127.3			134.6			(7.3		)	(5.4	)
Corporate and Other
Cost of product sold	15.4			17.7			(2.3		)	(13.0	)
Eliminations of Intersegment Sales
Cost of product sold	(26.1		)	(31.3		)	5.2			16.6
Total Consolidated
Cost of product sold	$	557.6		$	549.0		$	8.6		1.6

The cost of product sold and average cost per ton sold for our Owned and Operated Mines segment increased primarily as a result of higher direct operating costs related to weather interruptions, unplanned power plant outages at a small number of major customers, and the impact of production interruptions during maintenance downtime. In addition, we have experienced cost inflation on our explosives purchases and incurred additional labor costs associated with longer hauls and increased strip ratios, particularly at our Cordero Rojo mine.

Cost of product sold for our Logistics and Related Activities segment decreased primarily due to a reduction in the volume of domestic deliveries coordinated. Costs related to the increase in Asian deliveries through the port were offset by lower unit delivery costs. The Asian delivered tons that were coordinated during 2013 were delivered through the lower cost Westshore port.

Cost of product sold for our Corporate and Other segment decreased primarily due to lower costs at the Decker mine partially offset by the additional broker tons sold.

Operating Income

The following table presents operating income (in millions):

	Six Months Ended
	June 30,						Change
	2013			2012			Amount			Percent
Owned and Operated Mines
Operating income	$	27.1		$	71.7		$	(44.6	)	(62.2	)
Logistics and Related Activities
Operating income	$	27.6		$	40.4		$	(12.8	)	(31.7	)
Corporate and Other
Operating loss	$	(2.9	)	$	(6.2	)	$	3.3		53.2
Eliminations of Intersegment Sales
Operating loss	$	(0.2	)	$	(0.2	)	$	—		—
Total Consolidated
Operating income	$	51.7		$	105.8		$	(54.1	)	(51.1	)

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Operating income for our Logistics and Related Activities segment decreased primarily due to the revenue and cost of product sold factors previously discussed partially offset by the mark-to-market impact from our international coal forward contracts as a result of declining international coal market prices. The $26.2 million gain in 2013 was higher as compared to $18.1 million in 2012.

Operating loss for our Corporate and Other segment increased primarily to the revenue and cost of product sold factors previously discussed.

Other Income (Expense)

The following table presents other expense (in millions):

	Six Months Ended
	June 30,				Change
	2013		2012		Amount		Percent
Other expense	$	20.8	$	13.1	$	7.7	58.8

Other expense increased for 2013 compared to 2012 as a result of higher interest expense due to a reduction in the amount of interest capitalized in the current period.

Income Tax Provision

The following table presents income tax provision (in millions):

	Six Months Ended
	June 30,						Change
	2013			2012			Amount			Percent
Income tax expense	$	11.3		$	33.9		$	(22.6	)	(0.7	)
Effective tax rate	36.6		%	36.6		%	—			—

Our statutory income tax rate, including state income taxes, is 36%.

Liquidity and Capital Resources

	June 30,		December 31,
	2013		2012
	(in millions)
Cash and cash equivalents	$	199.7	$	197.7
Investments in marketable securities	80.5		80.3
Total	$	280.2	$	278.0

In addition to our cash and cash equivalents, our primary sources of liquidity are cash from our operations, investments in marketable securities, and borrowing capacity under CPE Resources’s revolving credit facility and Accounts Receivable Securitization Facility (“A/R Securitization Program”). In addition, we organized a capital leasing program that could grow over time up to $150 million for some of our future capital equipment purchases. These programs provide flexibility and liquidity to our capital structure. For further details on the A/R Securitization Program and credit facility, see below. For further details on the capital leasing program, see Note 7 to our notes to unaudited condensed consolidated financial statements in Item 1. Cash from operations depends on a number of factors beyond our control, such as the market price for our coal, the quantity of coal required by our customers, coal-fired electricity demand, regulatory changes and energy policies impacting our business, our costs of operating including the market price we pay for diesel fuel and other input costs, as well as costs of logistics including rail and port charges, and other risks and uncertainties, including those discussed in Item 1A “Risk Factors” in our 2012 Form 10-K.

Investments in marketable securities include highly-liquid securities which are investment grade. Our investment policy has the objective of minimizing the potential risk of principal loss and is intended to limit our credit exposure to any single issuer. Individual securities have various maturity dates; however, it is our expectation that we could sell any individual security in the secondary market at short notice allowing for improved liquidity.

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CPE Resources and certain of our subsidiaries are parties to the A/R Securitization Program. In January 2013, we formed CPE Receivables LLC (the “SPE”), a special purpose, bankruptcy-remote wholly-owned subsidiary to purchase, subject to certain exclusions, in a true sale, trade receivables generated by certain of our subsidiaries without recourse (other than customary indemnification obligations for breaches of specific representations and warranties), and then transfer undivided interests in up to $75 million of those accounts receivable to a financial institution for cash borrowings for our ultimate benefit. The total aggregate borrowings and letters of credit are limited by eligible accounts receivable, as defined under the terms of the A/R Securitization Program. At June 30, 2013, the A/R Securitization Program would have allowed for $51.9 million of borrowing capacity. There were no borrowings from the A/R Securitization Program at June 30, 2013.

On June 3, 2011, CPE Resources entered into an Amended and Restated Credit Agreement (the “Amended Credit Agreement”) which establishes a commitment to provide us with a senior secured revolving credit facility with a capacity of up to $500 million that can be used to borrow funds or issue letters of credit. The Amended Credit Agreement matures on June 3, 2016. We may request incremental term loans or increase the revolving commitments in an aggregate amount of up to $200 million subject to compliance with certain conditions. The Amended Credit Agreement imposes limitations on the ability of CPE Resources and its subsidiaries to make distributions and/or extend loans to CPE Inc.

The borrowing capacity under the Amended Credit Agreement is reduced by the amount of letters of credit issued. Our ability to borrow under our revolving credit facility is subject to the terms and conditions of the facility, including our compliance with financial and non-financial covenants. The financial covenants in the Amended Credit Agreement are based on EBITDA (which is defined in the Amended Credit Agreement and is not the same as EBITDA or Adjusted EBITDA otherwise presented), requiring us to maintain defined minimum levels of interest coverage and providing for a defined maximum leverage ratio. Specifically, the Amended Credit Agreement requires us to maintain (a) a ratio of EBITDA to consolidated net cash interest expense equal to or greater than (i) 2.50 to 1 through June 30, 2013 and (ii) 2.75 to 1 from July 1, 2013 to maturity, and (b) a ratio of funded debt to EBITDA equal to or less than (i) 3.75 to 1 through June 30, 2013 and (ii) 3.50 to 1 from July 1, 2013 to maturity. Our federal coal lease obligations are not considered debt under our covenant calculations. At June 30, 2013, we were in compliance with the covenants contained in our Amended Credit Agreement.

As of June 30, 2013, our borrowing capacity under the Amended Credit Agreement and the A/R Securitization Program was approximately $487 million. As a result of the decrease in the leverage ratio effective July 1, 2013 and assuming lower EBITDA as compared to the prior year, our actual borrowing capacity will be further reduced during the second half of 2013.

The indenture governing the senior notes also imposes limitations on the ability of CPE Resources and its subsidiaries to make distributions, and to extend loans and advances, to CPE Inc. Such limitations, taken as a whole, are less restrictive than those contained in the Amended Credit Agreement. CPE Resources is required to make semi-annual interest payments on its senior notes, which commenced on June 15, 2010.

The limitations in both the Amended Credit Agreement and the indenture have not had, nor are they expected to have, a negative impact upon the ability of CPE Resources to make distributions to CPE Inc.

We believe our sources of liquidity will be sufficient to fund our primary ordinary course uses of cash for the next 12 months, which include our costs of coal production and logistics services, coal lease installment payments for LBAs and other coal tracts, capital expenditures, interest on our debt, and payments on the tax agreement liability.

In the second quarter of 2013, we made payments of $9.6 million on committed LBAs. In the second half of 2013, we expect to make additional payments of $69.4 million related to committed coal leases. We will continue to explore opportunities to increase our reserve base by acquiring additional coal and surface rights. If we are successful in future bids for coal rights and other growth strategies, our cash flows could be significantly impacted as we would be required to make associated payments.

Our anticipated capital expenditures (excluding capitalized interest and federal lease payments), which we expect will be between $60 million and $70 million in 2013, include our estimates of expenditures necessary to keep our equipment fleets updated to maintain our mining productivity and competitive position and the addition of new equipment as necessary.

Based on our estimates, we expect to make payments on the tax agreement liability of $19.5 million in 2013, payments averaging approximately $12.6 million each year during 2014 to 2017, and additional payments in subsequent years.

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If we do not have sufficient resources from ongoing operations to satisfy our obligations or the timing of payments on our obligations does not coincide with cash inflows from operations, we may need to use our cash on hand and marketable securities or borrow under our line of credit. If the obligation is in excess of these amounts, we may need to seek additional borrowing sources or take other actions. Depending upon existing circumstances at the time, we may not be able to obtain additional funding on acceptable terms or at all. In addition, our existing debt instruments contain restrictive covenants, which may prohibit us from borrowing under our revolving credit facility or pursuing certain alternatives to obtain additional funding.

Overview of Cash Transactions

We started 2013 with $278.0 million of unrestricted cash and cash equivalents and investments in marketable securities. After capital expenditures and generating cash from our operating activities, we concluded the six months ended June 30, 2013 with cash and cash equivalents and investments in marketable securities of $280.2 million.

Cash Flows

	Six Months Ended
	June 30,						Change
	2013			2012			Amount			Percent
	(dollars in millions)
Beginning balance - cash and cash equivalents	$	197.7		$	404.2		$	(206.5	)	(51.1	)
Net cash provided by operating activities	44.3			81.3			(37.0		)	(45.5	)
Net cash used in investing activities	(32.5		)	(315.0		)	282.5			(89.7	)
Net cash used in financing activities	(9.8		)	(49.0		)	39.2				*
Ending balance - cash and cash equivalents	$	199.7		$	121.6		$	78.1		64.2

Beginning balance - marketable securities	$	80.3		$	75.2		$	5.1		6.8
Ending balance - marketable securities	$	80.5		$	100.2		$	(19.7	)	(19.7	)

* Not meaningful

Cash flows of CPE Inc. and CPE Resources are not significantly different.

The decrease in cash provided by operating activities for the six months ended June 30, 2013 as compared to the same period in 2012 was primarily due to a $54.9 million decrease in net income adjusted for noncash items, specifically unrealized derivative income and deferred taxes. This difference was offset by a smaller decrease in working capital of $17.9 million in 2013 as compared to 2012, primarily caused by the timing of payments on accounts payable and accrued expenses offset by the timing of receipts of accounts receivable.

The decrease in cash used in investing activities for the six months ended June 30, 2013 as compared to the same period in 2012 was primarily related to the acquisition of the Youngs Creek and CX Ranch coal and land assets, a $24.8 million increase in investments in marketable securities, and a $28.2 million increase in capitalized interest related to the North Maysdorf LBA partially offset by the release of the remaining $71.2 million of restricted cash in the six months ended June 30, 2012.

The decrease in cash used in financing activities for the six months ended June 30, 2013 as compared to the same period in 2012 was primarily due to the higher LBA payments made in the six months ended June 30, 2012 as compared to the same period in 2013.

Global Climate Change

Enactment of laws or passage of regulations regarding emissions from the combustion of coal by the U.S. or some of its states or by other countries, or other actions to limit such emissions, like the creation of mandatory use requirements for renewable fuel sources, could result in electricity generators switching from coal to other fuel sources. Additionally, the creation and issuance of subsidies designed to encourage use of alternative energy sources could decrease the demand of coal as an energy source. In June 2013, a Presidential Memorandum was issued to the U.S. Environmental Protection Agency (the “EPA”) directing the agency to issue a new proposal for carbon emission standards for new or future power plants under the Clean Air Act Section 111’s New Source Performance Standards program by September 20, 2013. The Presidential Memorandum also directs the EPA to propose carbon emission standards for emissions from existing power plants by June 1,

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2014, and to finalize the standards by June 2015. Furthermore, the Presidential Memorandum establishes a deadline of June 30, 2016 by which states must submit state implementation plans to the EPA for applying the standards to existing power plants in their states. Finally, the Presidential Memorandum includes a variety of measures to promote renewable energy including commitments to develop renewable energy on federal lands and provide funding for clean technology research. The potential financial impact on us of these and other future laws, regulations, or subsidies will depend upon the degree to which electricity generators diminish their reliance on coal as a fuel source as a result of the laws, regulations or subsidies. That, in turn, will depend on a number of factors, including the appeal and design of the subsidies being offered, the specific requirements imposed by any such laws or regulations such as mandating use by utilities of renewable fuel sources, the time periods over which those laws or regulations would be phased in and the state of commercial development and deployment of carbon capture and storage technologies. In view of the significant uncertainty surrounding each of these factors, it is not possible for us to reasonably predict the impact that any such laws or regulations may have on our results of operations, financial condition or cash flows. See Item 1, “Business—Environmental and Other Regulatory Matters—Global Climate Change” and Item 1A, “Risk Factors” in our 2012 Form 10-K for additional discussion regarding how climate change and other environmental regulatory matters may materially adversely impact our business.

Critical Accounting Policies and Estimates

Newly Adopted Accounting Standards and Recently Issued Accounting Pronouncements

See Note 2 to our notes to unaudited condensed consolidated financial statements in Item 1 for a discussion of newly adopted accounting standards and recently issued accounting pronouncements.

Item 3. Quantitative and Qualitative Disclosures About Market Risk.

We define market risk as the risk of economic loss as a consequence of the adverse movement of market rates and prices or credit standings. We believe our principal market risks are commodity price risk, interest rate risk and credit risk.

Commodity Price Risk

Market risk includes the potential for changes in the market value of our coal portfolio. Historically, we have principally managed the commodity price risk for our coal contract portfolio through the use of long-term coal supply agreements of varying terms and durations. As of June 30, 2013, we had committed to sell approximately 92.1 million tons during 2013, of which 88.6 million tons are under fixed-price contracts. A $1 change to the average coal sales price per ton for these 3.5 million unpriced tons would result in an approximate $3.5 million change to the coal sales revenue. In addition, we entered into certain forward financial contracts linked to Newcastle coal prices to help manage our exposure to variability in future international coal prices. As of June 30, 2013, we held coal forward contracts for approximately 2.2 million tons which will settle between 2013 and 2016. A $1 change to the market index price per ton for these coal forward contracts would result in an approximate $1.9 million change to operating income (expense). During the first quarter of 2013, we commenced the use of futures contracts to help manage our exposure to market changes in domestic coal prices. As of June 30, 2013, we held domestic coal futures contracts for approximately 1.3 million tons, which will settle in 2014 and 2015. A $1 change to the market index price per ton for these futures contracts would result in an approximate $1.3 million change to operating income (expense).

We also face price risk involving other commodities used in our production process, primarily diesel fuel. Based on our projections of our usage of diesel fuel for the next 12 months, and assuming that the average cost of diesel fuel increases by 10%, we would incur additional fuel costs of approximately $11.4 million over the next 12 months. In addition, we use costless collars to manage certain exposures to diesel fuel prices. As the band of the costless collar is greater than 10%, it had no impact on this calculation. The terms of the program are disclosed in Note 4 to our notes to unaudited condensed consolidated financial statements in Item 1. While we would not receive the full benefit of extreme price decreases, the collars mitigate the risk of extreme crude oil price increases and thereby increased diesel costs that would otherwise have a negative impact on cash flow.

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Interest Rate Risk

Our Amended Credit Agreement and A/R Securitization Program are subject to an adjustable interest rate. See Item 2 “Management’s Discussion and Analysis of Financial Condition and Results of Operations—Liquidity and Capital Resources.” We had no outstanding borrowings under our credit facility or A/R Securitization Program as of June 30, 2013. If we borrow funds under the revolving credit facility or A/R Securitization Program, we may be subject to increased sensitivity to interest rate movements. The $7.6 million of borrowings under the capital lease program are also subject to variable interest rates although any change to the rate would not have a significant impact on cash flow. Any future debt arrangements that we enter into may also have adjustable interest rates that may increase our sensitivity to interest rate movements.

Credit Risk

We are exposed to credit loss in the event of non-performance by our counterparties, which may include end-use customers, trading houses, brokers, and financial institutions that serve as counterparties to our derivative financial instruments and hold our investments. We attempt to manage this exposure by entering into agreements with counterparties that meet our credit standards and that are expected to fully satisfy their obligations under the contracts. These steps may not always be effective in addressing counterparty credit risk.

When appropriate (as determined by our credit management function), we have taken steps to reduce our credit exposure to customers that do not meet our credit standards or whose credit has deteriorated. These steps include obtaining letters of credit and requiring prepayments for shipments. See Item 1A “Risk Factors—Risks Related to Our Business and Industry—We are exposed to counterparty risk with our customers, trading partners, financial institutions, and other parties with whom we conduct business.” in our 2012 Form 10-K.

Item 4. Controls and Procedures.

Disclosure Controls and Procedures

CPE Inc. and CPE Resources each maintain disclosure controls and procedures that are designed to ensure that information required to be disclosed in the reports they file or submit under the Securities Exchange Act of 1934 (the “Exchange Act”) is recorded, processed, summarized and reported, within the time periods specified in the Securities and Exchange Commission’s rules and forms. These disclosure controls and procedures include, without limitation, controls and procedures designed to ensure that the information required to be disclosed by CPE Inc. and CPE Resources in the reports they file or submit under the Exchange Act is accumulated and communicated to senior management, including the principal executive officer and principal financial officer, as appropriate to allow timely decisions regarding required disclosure. The management of each of CPE Inc. and CPE Resources, with the participation of the Chief Executive Officer and Chief Financial Officer of each entity, has evaluated the disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Exchange Act) of each entity as of June 30, 2013, and has concluded that such disclosure controls and procedures are effective at the reasonable assurance level.

Internal Control over Financial Reporting

During the most recent fiscal quarter, there have been no changes to the internal control over financial reporting of either CPE Inc. or CPE Resources that materially affected, or are reasonably likely to materially affect, either entity’s internal control over financial reporting.

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PART II

OTHER INFORMATION

Item 1. Legal Proceedings.

See Note 9 to the unaudited condensed consolidated financial statements included in Part I, Item 1 of this report relating to certain legal proceedings, which information is incorporated by reference herein.

Item 1A. Risk Factors.

In addition to the other information set forth in this report, you should carefully consider the risks and uncertainties described in Item 1A of our 2012 Form 10-K. The risks described in our 2012 Form 10-K are not the only risks we may face. If any of those risk factors, as well as other risks and uncertainties that are not currently known to us or that we currently believe are not material, actually occur, our business, financial condition, results of operations and cash flows could be materially and adversely affected. In our judgment, there were no material changes in the risk factors as previously disclosed in Item 1A of our 2012 Form 10-K.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds.

None.

Item 3. Defaults Upon Senior Securities.

None.

Item 4. Mine Safety Disclosures.

The 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 95.1 to this Form 10-Q.

Item 5. Other Information.

None.

Item 6. Exhibits.

See Exhibit Index at page 57 of this report.

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SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrants have duly caused this report to be signed on their behalf by the undersigned, thereunto duly authorized.

	CLOUD PEAK ENERGY INC.


		By:	/s/ MICHAEL BARRETT
Date: July 30, 2013			Michael Barrett Executive Vice President and Chief Financial Officer (Principal Financial Officer and Duly Authorized Officer)

	CLOUD PEAK ENERGY RESOURCES LLC


		By:	/s/ MICHAEL BARRETT
Date: July 30, 2013			Michael Barrett Executive Vice President and Chief Financial Officer (Principal Financial Officer and Duly Authorized Officer)

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EXHIBIT INDEX

The exhibits below are numbered in accordance with the Exhibit Table of Item 601 of Regulation S-K.

Exhibit Number		Description of Documents

2.1		Purchase and Sale Agreement, dated as of June 29, 2012, among Arrowhead I LLC, Chevron USA Inc., CONSOL Energy Inc., Consolidation Coal Company and Reserve Coal Properties Company (incorporated by reference to Exhibit 2.1 to Cloud Peak Energy Inc.’s Current Report on Form 8-K filed on July 2, 2012 (File No. 001-34547))

2.2		Purchase and Sale Agreement, dated as of June 29, 2012, among Chevron USA Inc. and Arrowhead I LLC (incorporated by reference to Exhibit 2.2 to Cloud Peak Energy Inc.’s Current Report on Form 8-K filed on July 2, 2012 (File No. 001-34547))

2.3		Purchase and Sale Agreement, dated as of June 29, 2012, among CONSOL Energy Inc., Consolidation Coal Company, Reserve Coal Properties Company and Arrowhead I LLC (incorporated by reference to Exhibit 2.3 to Cloud Peak Energy Inc.’s Current Report on Form 8-K filed on July 2, 2012 (File No. 001-34547))

3.1		Amended and Restated Certificate of Incorporation of Cloud Peak Energy Inc. effective as of November 25, 2009 (incorporated by reference to Exhibit 3.2 to Amendment No. 3 to Cloud Peak Energy Inc.’s Form S-1 filed on November 2, 2009 (File No. 333-161293))

3.2		Amended and Restated Bylaws of Cloud Peak Energy Inc. effective as of November 25, 2009 (incorporated by reference to Exhibit 3.1 of Cloud Peak Energy Inc.’s Current Report on Form 8-K filed on December 2, 2009 (File No. 001-34547))

3.3		Amended and Restated Certificate of Formation of Cloud Peak Energy Resources LLC (incorporated herein by reference to Exhibit 3.1 to Cloud Peak Energy Resources LLC’s Registration Statement on Form S-4/A filed on August 17, 2010 (File No. 333-168639))

3.4		Third Amended and Restated Limited Liability Company Agreement of Cloud Peak Energy Resources LLC, dated as of November 19, 2009, by and among Cloud Peak Energy Inc., Rio Tinto Energy America Inc. and Kennecott Management Services Company (incorporated herein by reference to Exhibit 10.5 to Cloud Peak Energy Inc.’s Current Report on Form 8-K filed on November 25, 2009 (File No. 001-34547))

4.1		Form of stock certificate of Cloud Peak Energy Inc. (incorporated by reference to Exhibit 4.1 of the Amendment No. 5 to Cloud Peak Energy Inc.’s Form S-1 filed on November 16, 2009 (File No. 333-161293))

4.2		Indenture, dated as of November 25, 2009, by and among Cloud Peak Energy Resources LLC (and its subsidiaries listed on the signature page), Cloud Peak Energy Finance Corp., Wilmington Trust Company and Citibank, N.A. (incorporated herein by reference to Exhibit 4.1 to Cloud Peak Energy Inc.’s Current Report on Form 8-K filed on December 2, 2009 (File No. 001-34547))

4.3		Form of Exchange Notes (included in Exhibit 4.2 hereto)

10.1	*	Employment Agreement between Cloud Peak Energy Inc. and Bruce Jones dated as of July 8, 2013.

10.2		Cloud Peak Energy 2013 Annual Incentive Plan (incorporated herein by reference to Exhibit 10.1 to Cloud Peak Energy Inc.’s Current Report on Form 8-K filed on May 15, 2013 (File No. 001-34547))

12.1	*	Computation of Ratio of Earnings to Fixed Charges

31.1	*	Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 for Cloud Peak Energy Inc.

31.2	*	Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 for Cloud Peak Energy Inc.

31.3	*	Certification of Chief Executive Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 for Cloud Peak Energy Resources LLC

31.4	*	Certification of Chief Financial Officer pursuant to Section 302 of the Sarbanes-Oxley Act of 2002 for

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Exhibit Number		Description of Documents

		Cloud Peak Energy Resources LLC

32.1	*	Certification of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 for Cloud Peak Energy Inc.

32.2	*	Certification of Chief Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 for Cloud Peak Energy Inc.

32.3	*	Certification of Chief Executive Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 for Cloud Peak Energy Resources LLC

32.4	*	Certification of Chief Financial Officer pursuant to Section 906 of the Sarbanes-Oxley Act of 2002 for Cloud Peak Energy Resources LLC

95.1	*	Mine Safety Disclosure

101.INS*		XBRL Instance Document

101.SCH*		XBRL Taxonomy Extension Schema Document

101.CAL*		XBRL Taxonomy Calculation Linkbase Document

101.LAB*		XBRL Taxonomy Label Linkbase Document

101.PRE*		XBRL Taxonomy Presentation Linkbase Document

101.DEF*		XBRL Taxonomy Definition Document

* Filed or furnished herewith, as applicable