ALLIANCE RESOURCE PARTNERS LP - Quarter Report: 2014 March (Form 10-Q)

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UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

 

 

FORM 10-Q

 

xQUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF

THE SECURITIES EXCHANGE ACT OF 1934

 

For the quarterly period ended March 31, 2014

 

OR

 

oTRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF

THE SECURITIES EXCHANGE ACT OF 1934

 

For the transition period from ________________to________________

 

Commission File No.:  0-26823

 

 

 

ALLIANCE RESOURCE PARTNERS, L.P.

(Exact name of registrant as specified in its charter)

 

 

1717 South Boulder Avenue,  Suite 400, Tulsa, Oklahoma 74119

(Address of principal executive offices and zip code)

 

(918) 295-7600

(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. [X] Yes   [   ] 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).  [X ] Yes   [   ] 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 definitions of “large accelerated filer,” “accelerated filer” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.  (check one)

 

Large Accelerated Filer [X]	Accelerated Filer [   ]	Non-Accelerated Filer [   ]	Smaller Reporting Company [   ]
		(Do not check if smaller reporting company)

 

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

[   ] Yes   [X] No

 

As of May 9, 2014, 37,030,317 common units are outstanding.

 

 

Table of Contents

 

TABLE OF CONTENTS

 

PART I

 

FINANCIAL INFORMATION

 

		Page
ITEM 1.	Financial Statements (Unaudited)
	ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES
	Condensed Consolidated Balance Sheets as of March 31, 2014 and December 31, 2013	1
	Condensed Consolidated Statements of Income for the three months ended March 31, 2014 and 2013	2
	Condensed Consolidated Statements of Comprehensive Income for the three months ended March 31, 2014 and 2013	3
	Condensed Consolidated Statements of Cash Flows for the three months ended March 31, 2014 and 2013	4
	Notes to Condensed Consolidated Financial Statements	5
ITEM 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	16
ITEM 3.	Quantitative and Qualitative Disclosures about Market Risk	26
ITEM 4.	Controls and Procedures	27
	Forward-Looking Statements	28
PART II
OTHER INFORMATION
ITEM 1.	Legal Proceedings	30
ITEM 1A.	Risk Factors	30
ITEM 2.	Unregistered Sales of Equity Securities and Use of Proceeds	30
ITEM 3.	Defaults Upon Senior Securities	30
ITEM 4.	Mine Safety Disclosures	30
ITEM 5.	Other Information	30
ITEM 6.	Exhibits	31

 

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PART I

 

FINANCIAL INFORMATION

 

ITEM 1.                FINANCIAL STATEMENTS

 

ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands, except unit data)

(Unaudited)

 

ASSETS		March 31,			December 31,
		2014			2013
CURRENT ASSETS:
Cash and cash equivalents		$	14,396		$	93,654
Trade receivables		199,554			153,662
Other receivables		294			776
Due from affiliates		2,497			1,964
Inventories		68,751			44,214
Advance royalties		11,454			11,454
Prepaid expenses and other assets		9,954			16,186
Total current assets		306,900			321,910
PROPERTY, PLANT AND EQUIPMENT:
Property, plant and equipment, at cost		2,681,406			2,645,872
Less accumulated depreciation, depletion and amortization		(1,062,256)			(1,031,493)
Total property, plant and equipment, net		1,619,150			1,614,379
OTHER ASSETS:
Advance royalties		20,741			18,813
Due from affiliate		11,458			11,560
Equity investments in affiliates		154,029			130,410
Other long-term assets		23,680			24,826
Total other assets		209,908			185,609
TOTAL ASSETS		$	2,135,958		$	2,121,898
LIABILITIES AND PARTNERS’ CAPITAL
CURRENT LIABILITIES:
Accounts payable		$	83,860		$	79,371
Due to affiliates		202			290
Accrued taxes other than income taxes		25,060			19,061
Accrued payroll and related expenses		43,116			47,105
Accrued interest		6,302			996
Workers’ compensation and pneumoconiosis benefits		9,237			9,065
Current capital lease obligations		1,307			1,288
Other current liabilities		17,130			18,625
Current maturities, long-term debt		43,000			36,750
Total current liabilities		229,214			212,551
LONG-TERM LIABILITIES:
Long-term debt, excluding current maturities		790,000			831,250
Pneumoconiosis benefits		49,698			48,455
Accrued pension benefit		17,544			18,182
Workers’ compensation		54,857			54,949
Asset retirement obligations		81,324			80,807
Long-term capital lease obligations		16,758			17,135
Other liabilities		6,407			7,332
Total long-term liabilities		1,016,588			1,058,110
Total liabilities		1,245,802			1,270,661
COMMITMENTS AND CONTINGENCIES
PARTNERS’ CAPITAL:
Limited Partners - Common Unitholders 37,030,317 and 36,963,054 units outstanding, respectively		1,165,621			1,128,519
General Partners’ deficit		(265,708)			(267,563)
Accumulated other comprehensive loss		(9,757)			(9,719)
Total Partners’ Capital		890,156			851,237
TOTAL LIABILITIES AND PARTNERS’ CAPITAL		$	2,135,958		$	2,121,898

 

See notes to condensed consolidated financial statements.

 

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ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES

 

CONDENSED CONSOLIDATED STATEMENTS OF INCOME

(In thousands, except unit and per unit data)

(Unaudited)

 

		Three Months Ended March 31,
		2014				2013
SALES AND OPERATING REVENUES:
Coal sales		$		525,545		$		534,509
Transportation revenues		6,005				6,934
Other sales and operating revenues		10,488				6,612
Total revenues		542,038				548,055
EXPENSES:
Operating expenses (excluding depreciation, depletion and amortization)		322,242				348,575
Transportation expenses		6,005				6,934
Outside coal purchases		2				602
General and administrative		17,435				15,246
Depreciation, depletion and amortization		66,841				64,382
Total operating expenses		412,525				435,739
INCOME FROM OPERATIONS		129,513				112,316
Interest expense (net of interest capitalized for the three months ended March 31, 2014 and 2013 of $772 and $2,531, respectively)		(8,063)				(6,618)
Interest income		389				134
Equity in loss of affiliates, net		(6,241)				(3,867)
Other income		306				274
INCOME BEFORE INCOME TAXES		115,904				102,239
INCOME TAX BENEFIT		-				(698)
NET INCOME		$	115,904			$	102,937
GENERAL PARTNERS’ INTEREST IN NET INCOME		$	33,368			$	29,770
LIMITED PARTNERS’ INTEREST IN NET INCOME		$	82,536			$	73,167
BASIC AND DILUTED NET INCOME PER LIMITED PARTNER UNIT (Note 7)		$	2.20			$	1.95
DISTRIBUTIONS PAID PER LIMITED PARTNER UNIT		$	1.1975			$	1.1075
WEIGHTED AVERAGE NUMBER OF UNITS OUTSTANDING – BASIC AND DILUTED		36,997,433				36,919,002

 

See notes to condensed consolidated financial statements.

 

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ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES

 

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME

(In thousands)

(Unaudited)

 

 

		Three Months Ended March 31,
		2014			2013
NET INCOME		$	115,904		$	102,937
OTHER COMPREHENSIVE (LOSS)/INCOME:
Defined benefit pension plan:
Amortization of actuarial loss (1)		225			559
Total defined benefit pension plan adjustments		225			559
Pneumoconiosis benefits:
Amortization of actuarial (gain)/loss (1)		(263)			168
Total pneumoconiosis benefits adjustments		(263)			168
OTHER COMPREHENSIVE (LOSS)/INCOME		(38)			727
TOTAL COMPREHENSIVE INCOME		$	115,866		$	103,664

 

(1)          Amortization of actuarial (gain)/loss is included in the computation of net periodic benefit cost (see Notes 8 and 10 for additional details).

 

See notes to condensed consolidated financial statements.

 

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ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES

 

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

(Unaudited)

 

		Three Months Ended March 31,
		2014			2013
CASH FLOWS PROVIDED BY OPERATING ACTIVITIES		$	140,099		$	199,478
CASH FLOWS FROM INVESTING ACTIVITIES:
Property, plant and equipment:
Capital expenditures		(69,463)			(70,306		)
Changes in accounts payable and accrued liabilities		(3,745)			(7,608		)
Proceeds from sale of property, plant and equipment		—			9
Purchases of equity investments in affiliate		(30,000)			(29,700		)
Payments to affiliate for acquisition and development of coal reserves		(1,401)			(12,064		)
Advances/loans to affiliate		—			(1,643		)
Net cash used in investing activities		(104,609)			(121,312		)
CASH FLOWS FROM FINANCING ACTIVITIES:
Borrowings under revolving credit facilities		82,800			45,000
Payments under revolving credit facilities		(117,800)			(50,000		)
Payments on capital lease obligations		(358)			(284		)
Net settlement of employee withholding taxes on vesting of Long-Term Incentive Plan		(2,991)			(3,015		)
Cash contributions by General Partners		111			114
Distributions paid to Partners		(76,510)			(69,587		)
Net cash used in financing activities		(114,748)			(77,772		)
NET CHANGE IN CASH AND CASH EQUIVALENTS		(79,258)			394
CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD		93,654			28,283
CASH AND CASH EQUIVALENTS AT END OF PERIOD		$	14,396		$	28,677
SUPPLEMENTAL CASH FLOW INFORMATION:
Cash paid for interest		$	3,255		$	3,906
NON-CASH INVESTING AND FINANCING ACTIVITY:
Accounts payable for purchase of property, plant and equipment		$	14,179		$	13,364
Market value of common units issued under Long-Term Incentive and Directors Deferred Compensation Plans before minimum statutory tax withholding requirements		$	8,417		$	8,583

 

See notes to condensed consolidated financial statements.

 

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ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES

 

NOTES TO CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

(Unaudited)

 

1.                                    ORGANIZATION AND PRESENTATION

 

Significant Relationships Referenced in Notes to Condensed Consolidated Financial Statements

 

·                 References to “we,” “us,” “our” or “ARLP Partnership” mean the business and operations of Alliance Resource Partners, L.P., the parent company, as well as its consolidated subsidiaries.

·                 References to “ARLP” mean Alliance Resource Partners, L.P., individually as the parent company, and not on a consolidated basis.

·                 References to “MGP” mean Alliance Resource Management GP, LLC, the managing general partner of Alliance Resource Partners, L.P, also referred to as our managing general partner.

·                 References to “SGP” mean Alliance Resource GP, LLC, the special general partner of Alliance Resource Partners, L.P., also referred to as our special general partner.

·                 References to “Intermediate Partnership” mean Alliance Resource Operating Partners, L.P., the intermediate partnership of Alliance Resource Partners, L.P., also referred to as our intermediate partnership.

·                 References to “Alliance Coal” mean Alliance Coal, LLC, the holding company for the operations of Alliance Resource Operating Partners, L.P., also referred to as our operating subsidiary.

·                 References to “AHGP” mean Alliance Holdings GP, L.P., individually as the parent company, and not on a consolidated basis.

·                 References to “AGP” mean Alliance GP, LLC, the general partner of Alliance Holdings GP, L.P.

 

Organization

 

ARLP is a Delaware limited partnership listed on the NASDAQ Global Select Market under the ticker symbol “ARLP.”  ARLP was formed in May 1999 to acquire, upon completion of ARLP’s initial public offering on August 19, 1999, certain coal production and marketing assets of Alliance Resource Holdings, Inc., a Delaware corporation (“ARH”), consisting of substantially all of ARH’s operating subsidiaries, but excluding ARH.  ARH is owned by Joseph W. Craft III, the President and Chief Executive Officer and a Director of our managing general partner, and Kathleen S. Craft.  SGP, a Delaware limited liability company, is owned by ARH and holds a 0.01% general partner interest in each of ARLP and the Intermediate Partnership.

 

We are managed by our managing general partner, MGP, a Delaware limited liability company, which holds a 0.99% and a 1.0001% managing general partner interest in ARLP and the Intermediate Partnership, respectively, and a 0.001% managing member interest in Alliance Coal.  AHGP is a Delaware limited partnership that was formed to become the owner and controlling member of MGP.  AHGP completed its initial public offering on May 15, 2006.  AHGP owns directly and indirectly 100% of the members’ interest of MGP, the incentive distribution rights (“IDR”) in ARLP and 15,544,169 common units of ARLP.

 

Basis of Presentation

 

The accompanying condensed consolidated financial statements include the accounts and operations of the ARLP Partnership and present our financial position as of March 31, 2014 and December 31, 2013, and the results of our operations, comprehensive income and cash flows for the three months ended March 31, 2014 and 2013.  All of our intercompany transactions and accounts have been eliminated.

 

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These condensed consolidated financial statements and notes are unaudited. However, in the opinion of management, these financial statements reflect all adjustments (which include only normal recurring adjustments) necessary for a fair presentation of the results for the periods presented.  Results for interim periods are not necessarily indicative of results for a full year.

 

These condensed consolidated financial statements and notes are prepared pursuant to the rules and regulations of the Securities and Exchange Commission for interim reporting and should be read in conjunction with the consolidated financial statements and notes included in our Annual Report on Form 10-K for the year ended December 31, 2013.

 

Use of Estimates

 

The preparation of the ARLP Partnership’s condensed consolidated financial statements in conformity with generally accepted accounting principles (“GAAP”) of the United States (“U.S.”) requires management to make estimates and assumptions that affect the reported amounts and disclosures in our condensed consolidated financial statements.  Actual results could differ from those estimates.

 

2.                                    NEW ACCOUNTING STANDARDS

 

New Accounting Standards Issued and Not Yet Adopted

 

In April 2014, the Financial Accounting Standards Board (“FASB”) issued Accounting Standards Update (“ASU”) 2014-08, Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity (“ASU 2014-08”).  ASU 2014-08 changes the requirements for reporting discontinued operations in Accounting Standards Codification 205, Presentation of Financial Statements, by updating the criteria for determining which disposals can be presented as discontinued operations and requires new disclosures of both discontinued operations and certain other disposals that do not meet the definition of discontinued operations.  ASU 2014-08 is effective for fiscal years, and interim periods within those years, beginning after December 15, 2014.  We do not anticipate the adoption of ASU 2014-08 on January 1, 2015 will have a material impact on our consolidated financial statements.

 

3.                                    CONTINGENCIES

 

Various lawsuits, claims and regulatory proceedings incidental to our business are pending against the ARLP Partnership.  We record an accrual for a potential loss related to these matters when, in management’s opinion, such loss is probable and reasonably estimable.  Based on known facts and circumstances, we believe the ultimate outcome of these outstanding lawsuits, claims and regulatory proceedings will not have a material adverse effect on our financial condition, results of operations or liquidity.  However, if the results of these matters were different from management’s current opinion and in amounts greater than our accruals, then they could have a material adverse effect.

 

4.                                    FAIR VALUE MEASUREMENTS

 

We apply the provisions of FASB ASC 820, Fair Value Measurement, which, among other things, defines fair value, requires disclosures about assets and liabilities carried at fair value and establishes a hierarchal disclosure framework based upon the quality of inputs used to measure fair value.

 

Valuation techniques are based upon observable and unobservable inputs.  Observable inputs reflect market data obtained from independent sources, while unobservable inputs reflect our own market assumptions.  These two types of inputs create the following fair value hierarchy:

 

·                 Level 1 – Quoted prices for identical instruments in active markets.

 

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·                 Level 2 – Quoted prices for similar instruments in active markets; quoted prices for identical or similar instruments in markets that are not active; and model derived valuations whose inputs are observable or whose significant value drivers are observable.

·                 Level 3 – Instruments whose significant value drivers are unobservable.

 

The carrying amounts for cash equivalents, accounts receivable, accounts payable, due from affiliates and due to affiliates approximate fair value because of the short maturity of those instruments.  At March 31, 2014 and December 31, 2013, the estimated fair value of our long-term debt, including current maturities, was approximately $845.5 million and $884.8 million, respectively, based on interest rates that we believe are currently available to us for issuance of debt with similar terms and remaining maturities (Note 5). The fair value of debt, which is based upon interest rates for similar instruments in active markets, is classified as a Level 2 measurement under the fair value hierarchy.

 

5.                                    LONG-TERM DEBT

 

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

 

		March 31, 2014			December 31, 2013
Revolving Credit facility		$	215,000		$	250,000
Senior notes		18,000			18,000
Series A senior notes		205,000			205,000
Series B senior notes		145,000			145,000
Term loan		250,000			250,000
		833,000			868,000
Less current maturities		(43,000)			(36,750)
Total long-term debt		$	790,000		$	831,250

 

Our Intermediate Partnership has $18.0 million in senior notes (“Senior Notes”), $205.0 million in Series A and $145.0 million in Series B senior notes (collectively, the “2008 Senior Notes”), a $700.0 million revolving credit facility (“Revolving Credit Facility”) and a $250.0 million term loan (collectively, with the Senior Notes, the 2008 Senior Notes and the Revolving Credit Facility, the “ARLP Debt Arrangements”), which are guaranteed by all of the material direct and indirect subsidiaries of our Intermediate Partnership. The ARLP Debt Arrangements contain various covenants affecting our Intermediate Partnership and its subsidiaries restricting, among other things, the amount of distributions by our Intermediate Partnership, the incurrence of additional indebtedness and liens, the sale of assets, the making of investments, the entry into mergers and consolidations and the entry into transactions with affiliates, in each case subject to various exceptions.  The ARLP Debt Arrangements also require the Intermediate Partnership to remain in control of a certain amount of mineable coal reserves relative to its annual production.  In addition, the ARLP Debt Arrangements require our Intermediate Partnership to maintain (a) debt to cash flow ratio of not more than 3.0 to 1.0 and (b) cash flow to interest expense ratio of not less than 3.0 to 1.0, in each case, during the four most recently ended fiscal quarters.  The debt to cash flow ratio and cash flow to interest expense ratio were 1.17 to 1.0 and 20.4 to 1.0, respectively, for the trailing twelve months ended March 31, 2014.  We were in compliance with the covenants of the ARLP Debt Arrangements as of March 31, 2014.

 

At March 31, 2014, we had borrowings of $215.0 million and $24.2 million of letters of credit outstanding with $460.8 million available for borrowing under the Revolving Credit Facility.  We utilize the Revolving Credit Facility, as appropriate, for working capital requirements, anticipated capital expenditures and investments in affiliates, scheduled debt payments and distribution payments.  We incur an annual commitment fee of 0.25% on the undrawn portion of the Revolving Credit Facility.

 

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6.                                    WHITE OAK TRANSACTIONS

 

On September 22, 2011 (the “Transaction Date”), we entered into a series of transactions with White Oak Resources LLC (“White Oak”) and related entities to support development of a longwall mining operation currently under construction.  The transactions feature several components, including an equity investment in White Oak (represented by “Series A Units” containing certain distribution and liquidation preferences), the acquisition and lease-back of certain coal reserves and surface rights and a construction loan.  Our initial investment funding to White Oak at the Transaction Date, consummated utilizing existing cash on hand, was $69.5 million and we have funded White Oak $248.1 million between the Transaction Date and March 31, 2014.  We expect to fund a total of approximately $395.5 million to $425.5 million from the Transaction Date through December 31, 2015, which includes the funding made to White Oak through March 31, 2014 discussed above.  On the Transaction Date, we also entered into a coal handling and services agreement, pursuant to which we constructed and are operating a preparation plant and other surface facilities.  We expect to fund these additional commitments utilizing existing cash balances, future cash flows from operations, borrowings under credit facilities and cash provided from the issuance of debt or equity.  The following information discusses each component of these transactions in further detail.

 

Hamilton County, Illinois Reserve Acquisition

 

On the Transaction Date, Alliance WOR Properties, LLC (“WOR Properties”) acquired from White Oak the rights to approximately 204.9 million tons of proven and probable high-sulfur coal reserves, of which 105.2 million tons are currently being developed for future mining by White Oak, and certain surface properties and rights in Hamilton County, Illinois (the “Reserve Acquisition”), which is adjacent to White County, Illinois, where our White County Coal, LLC Pattiki mine is located.  The asset purchase price of $33.8 million cash paid at closing was allocated to owned and leased coal rights.  Between the Transaction Date and December 31, 2012, WOR Properties provided $51.6 million to White Oak for development of the acquired coal reserves, fulfilling its initial commitment for further development funding.  During the twelve months ended December 31, 2013, WOR Properties acquired from White Oak, for $25.3 million cash paid at various closings, an additional 90.1 million tons of reserves.  During the three months ended March 31, 2014, WOR Properties acquired from White Oak, for $1.4 million cash paid at closing, an additional 5.1 million tons of reserves.  Of the additional tons acquired in 2013 and the three months ended March 31, 2014, 48.5 million tons are currently being developed for future mining by White Oak.  At March 31, 2014, WOR Properties has provided $112.1 million to acquire a total of 300.1 million tons of coal reserves and fund the development of the acquired reserves.  WOR Properties has a remaining commitment of $27.9 million for additional coal reserve acquisitions and development funding.

 

Equity Investment – Series A Units

 

Concurrent with the Reserve Acquisition, our subsidiary, Alliance WOR Processing, LLC (“WOR Processing”), made an initial equity investment of $35.7 million in White Oak to purchase Series A Units representing ownership in White Oak.  WOR Processing purchased $129.3 million of additional Series A Units between the Transaction Date and December 31, 2013, and fulfilled WOR Processing’s minimum equity investment commitment of $150.0 million.  During the three months ended March 31, 2014, WOR Processing purchased $30.0 million of additional Series A Units, bringing the total investment in Series A Units to $195.0 million at March 31, 2014.

 

WOR Processing’s ownership and member’s voting interest in White Oak at March 31, 2014 were 29.0% based upon currently outstanding voting units.  The remainder of the equity ownership in White Oak, represented by Series B Units, is held by other investors and members of White Oak management.

 

We continually review all rights provided to WOR Processing and us by various agreements with White Oak and continue to conclude all such rights are protective or participating in nature and do not

 

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provide WOR Processing or us the ability to unilaterally direct any of the primary activities of White Oak that most significantly impact its economic performance.  As such, we recognize WOR Processing’s interest in White Oak as an equity investment in affiliate in our consolidated balance sheets.  As of March 31, 2014, WOR Processing had invested $195.0 million in Series A Units of White Oak equity, which represents our current maximum exposure to loss as a result of our equity investment in White Oak exclusive of capitalized interest.  White Oak has made no distributions to us.

 

We record WOR Processing’s equity in earnings or losses of affiliates under the hypothetical liquidation at book value method of accounting due to the preferences to which WOR Processing is entitled on distributions.  For the three months ended March 31, 2014 and 2013, we were allocated losses of $6.3 million and $4.2 million, respectively.

 

Services Agreement

 

Simultaneous with the closing of the Reserve Acquisition, WOR Processing entered into a Coal Handling and Preparation Agreement with White Oak pursuant to which WOR Processing committed to construct and operate a coal preparation plant and related facilities and a rail loop and loadout facility to service the White Oak longwall Mine No. 1.  For the quarter ended March 31, 2014, WOR Processing earned throughput fees of $3.6 million from White Oak for processing and loading coal through the facilities.

 

In addition, the Intermediate Partnership agreed to loan $10.5 million to White Oak for the construction of various assets on the surface property, including but not limited to, a bathhouse, office and warehouse (“Construction Loan”).  The Construction Loan has a term of 20 years, with repayment scheduled to begin in 2015.  White Oak had borrowed the entire amount available under the Construction Loan as of March 31, 2014.

 

7.                                    NET INCOME PER LIMITED PARTNER UNIT

 

We apply the provisions of FASB ASC 260, Earnings Per Share, which requires the two-class method in calculating basic and diluted earnings per unit (“EPU”).  Net income is allocated to the general partners and limited partners in accordance with their respective partnership percentages, after giving effect to any special income or expense allocations, including incentive distributions to our managing general partner, the holder of the IDR pursuant to our partnership agreement, which are declared and paid following the end of each quarter. Under the quarterly IDR provisions of our partnership agreement, our managing general partner is entitled to receive 15% of the amount we distribute in excess of $0.275 per unit, 25% of the amount we distribute in excess of $0.3125 per unit, and 50% of the amount we distribute in excess of $0.375 per unit.  Our partnership agreement contractually limits our distributions to available cash; therefore, undistributed earnings of the ARLP Partnership are not allocated to the IDR holder.  In addition, our outstanding awards under our Long-Term Incentive Plan (“LTIP”) and phantom units in notional accounts under our Supplemental Executive Retirement Plan (“SERP”) and the MGP Amended and Restated Deferred Compensation Plan for Directors (“Deferred Compensation Plan”) include rights to nonforfeitable distributions or distribution equivalents and are therefore considered participating securities.  As such, we allocate undistributed and distributed earnings to these outstanding awards in our calculation of EPU.

 

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The following is a reconciliation of net income used for calculating basic earnings per unit and the weighted average units used in computing EPU for the three months ended March 31, 2014 and 2013 (in thousands, except per unit data):

 

		Three Months Ended March 31,
		2014			2013
Net income		$	115,904		$	102,937
Adjustments:
Managing general partner’s priority distributions		(31,684)			(28,277)
General partners’ 2% equity ownership		(1,684)			(1,493)
Limited partners’ interest in net income		82,536			73,167
Less:
Distributions to participating securities		(708)			(569)
Undistributed earnings attributable to participating securities		(559)			(432)
Net income available to limited partners		$	81,269		$	72,166
Weighted average limited partner units outstanding — basic and diluted		36,997			36,919
Basic and diluted net income per limited partner unit (1)		$	2.20		$	1.95

 

(1)          Diluted EPU gives effect to all dilutive potential common units outstanding during the period using the treasury stock method. Diluted EPU excludes all dilutive potential units calculated under the treasury stock method if their effect is anti-dilutive.  For the three months ended March 31, 2014 and 2013, LTIP, SERP and Deferred Compensation Plan units of 373,896 and 324,315 respectively, were considered anti-dilutive under the treasury stock method.

 

On April 28, 2014, we also announced a two-for-one split of our common units. The unit split will take place in the form of a one unit distribution on each unit outstanding, with units to be distributed on June 16, 2014 to unitholders of record as of May 30, 2014. This unit split will result in the issuance of approximately 37.0 million common units. Following the unit split, the quarterly distribution per unit will be reduced by half; for example, the distribution for the quarter ended March 31, 2014 of $1.2225 per unit would become $0.61125 per unit, or an annualized rate of $2.445 per unit. Also following the unit split, the target threshold for the IDR per unit will be reduced by half and accordingly, the quarterly IDR paid will remain unchanged. The following pro forma net income per limited partner unit assumes a two-for-one split on June 16, 2014:

 

		Three Months Ended March 31,
		2014			2013
PRO FORMA BASIC AND DILUTED NET INCOME PER LIMITED PARTNER UNIT		$	1.10		$	0.98

 

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8.                                    WORKERS’ COMPENSATION AND PNEUMOCONIOSIS

 

The changes in the workers’ compensation liability (including current and long-term liability balances) for each of the periods presented were as follows (in thousands):

 

		Three Months Ended March 31,
		2014			2013
Beginning balance		$	62,909		$	77,046
Accruals increase		2,183			3,965
Payments		(2,749)			(2,876)
Interest accretion		646			620
Ending balance		$	62,989		$	78,755

 

Certain of our mine operating entities are liable under state statutes and the Federal Coal Mine Health and Safety Act of 1969, as amended, to pay pneumoconiosis, or black lung, benefits to eligible employees and former employees and their dependents.  Components of the net periodic benefit cost for each of the periods presented are as follows (in thousands):

 

		Three Months Ended March 31,
		2014			2013
Service cost		$	857		$	954
Interest cost		566			563
Amortization of net (gain)/loss (1)		(263)			168
Net periodic benefit cost		$	1,160		$	1,685

 

(1)      Amortization of net (gain)/loss is included in the operating expenses line item within our condensed consolidated statements of income.

 

9.                                    COMPENSATION PLANS

 

Long-Term Incentive Plan

 

We have the LTIP for certain employees and officers of our managing general partner and its affiliates who perform services for us.  The LTIP awards are grants of non-vested “phantom” or notional units, which upon satisfaction of vesting requirements, entitle the LTIP participant to receive ARLP common units.  Annual grant levels and vesting provisions for designated participants are recommended by our President and Chief Executive Officer, subject to review and approval of the compensation committee of the MGP board of directors (the “Compensation Committee”).  On January 22, 2014, the Compensation Committee determined that the vesting requirements for the 2011 grants of 101,371 restricted units (which is net of 7,045 forfeitures) had been satisfied as of January 1, 2014.  As a result of this vesting, on February 14, 2014, we issued 64,305 unrestricted common units to the LTIP participants. The remaining units were settled in cash to satisfy the individual statutory minimum tax obligations of the LTIP participants.  On January 22, 2014, the Compensation Committee authorized additional grants of up to 185,205 restricted units, of which 175,205 were granted during the three months ended March 31, 2014 and will vest on January 1, 2017, subject to satisfaction of certain financial tests.  The fair value of these 2014 grants is equal to the intrinsic value at the date of grant, which was $81.16 per unit.  LTIP expense was $2.1 million and $1.7 million for the three months ended March 31, 2014 and 2013, respectively.  After consideration of the January 1, 2014 vesting and subsequent issuance of 64,305 common units, approximately 2.0 million units remain available under the LTIP for issuance in the future, assuming all

 

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grants issued in 2012, 2013 and 2014 currently outstanding are settled with common units, without reduction for tax withholding, and no future forfeitures occur.

 

As of March 31, 2014, there was $19.9 million in total unrecognized compensation expense related to the non-vested LTIP grants that are expected to vest.  That expense is expected to be recognized over a weighted-average period of 1.9 years.  As of March 31, 2014, the intrinsic value of the non-vested LTIP grants was $35.5 million.  As of March 31, 2014, the total obligation associated with the LTIP was $10.1 million and is included in the partners’ capital-limited partners line item in our condensed consolidated balance sheets.

 

As provided under the distribution equivalent rights provisions of the LTIP, all non-vested grants include contingent rights to receive quarterly cash distributions in an amount equal to the cash distributions we make to unitholders during the vesting period.

 

SERP and Directors Deferred Compensation Plan

 

We utilize the SERP to provide deferred compensation benefits for certain officers and key employees. All allocations made to participants under the SERP are made in the form of “phantom” ARLP units.  The SERP is administered by the Compensation Committee.

 

Our directors participate in the Deferred Compensation Plan. Pursuant to the Deferred Compensation Plan, for amounts deferred either automatically or at the election of the director, a notional account is established and credited with notional common units of ARLP, described in the Deferred Compensation Plan as “phantom” units.

 

For both the SERP and Deferred Compensation Plan, when quarterly cash distributions are made with respect to ARLP common units, an amount equal to such quarterly distribution is credited to each participant’s notional account as additional phantom units.  All grants of phantom units under the SERP and Deferred Compensation Plan vest immediately.

 

For the three months ended March 31, 2014 and 2013, SERP and Deferred Compensation Plan participant notional account balances were credited with a total of 2,844 and 3,937 phantom units, respectively, and the fair value of these phantom units was $81.34 per unit and $61.67 per unit, respectively, on a weighted-average basis.  Total SERP and Deferred Compensation Plan expense was approximately $0.3 million for the three months ended March 31, 2014 and 2013, respectively.

 

As of March 31, 2014, there were 173,546 total phantom units outstanding under the SERP and Deferred Compensation Plan and the total intrinsic value of the SERP and Deferred Compensation Plan phantom units was $14.6 million.  As of March 31, 2014, the total obligation associated with the SERP and Deferred Compensation Plan was $11.6 million and is included in the partners’ capital-limited partners line item in our condensed consolidated balance sheets.  On February 14, 2014, we issued 2,958 ARLP common units to directors under the Deferred Compensation Plan.

 

10.                            COMPONENTS OF PENSION PLAN NET PERIODIC BENEFIT COSTS

 

Eligible employees at certain of our mining operations participate in a defined benefit plan (the “Pension Plan”) that we sponsor.  The benefit formula for the Pension Plan is a fixed dollar unit based on years of service.

 

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Components of the net periodic benefit cost for each of the periods presented are as follows (in thousands):

 

		Three Months Ended March 31,
		2014				2013
Service cost		$	543			$	760
Interest cost		1,019				852
Expected return on plan assets		(1,401		)		(1,233		)
Amortization of net loss (1)		225				559
Net periodic benefit cost		$	386			$	938

 

(1)          Amortization of net loss is included in the operating expenses line item within our condensed consolidated statements of income.

 

We previously disclosed in our financial statements for the year ended December 31, 2013 that we expected to contribute $3.6 million to the Pension Plan in 2014.  As of March 31, 2014, we made a contribution payment of $0.8 million to the Pension Plan for the 2013 plan year.  On April 15, 2014, we made a contribution payment of $0.8 million for the 2014 plan year.  We expect to make additional contributions of $0.3 million for the 2013 plan year and $1.7 million for the 2014 plan year for the remainder of 2014 and, therefore, will contribute approximately $3.6 million to the Pension Plan in 2014.

 

11.       SEGMENT INFORMATION

 

We operate in the eastern U.S. as a producer and marketer of coal to major utilities and industrial users.  We aggregate multiple operating segments into four reportable segments: the Illinois Basin, Appalachia, White Oak and Other and Corporate.  The first two reportable segments correspond to major coal producing regions in the eastern U.S.  Similar economic characteristics for our operating segments within each of these two reportable segments generally include coal quality, geology, coal marketing opportunities, mining and transportation methods and regulatory issues.  The White Oak reportable segment includes our activities associated with the White Oak longwall Mine No. 1 development project more fully described below.

 

The Illinois Basin reportable segment is comprised of multiple operating segments, including Webster County Coal, LLC’s Dotiki mining complex, Gibson County Coal, LLC’s mining complex, which includes the Gibson North mine and Gibson South mine, Hopkins County Coal, LLC’s Elk Creek mining complex, White County Coal, LLC’s Pattiki mining complex, Warrior Coal, LLC’s mining complex, Sebree Mining, LLC’s mining complex, which includes the Onton mine, and River View Coal, LLC’s mining complex.  The development of the Gibson South mine is currently underway with incidental production beginning in April 2014.

 

The Appalachian reportable segment is comprised of multiple operating segments, including the Mettiki mining complex, the Tunnel Ridge, LLC mining complex, the MC Mining, LLC mining complex and the Penn Ridge Coal, LLC (“Penn Ridge”) property.  The Mettiki mining complex includes Mettiki Coal (WV), LLC’s Mountain View mine, Mettiki Coal, LLC’s preparation plant and a small third-party mining operation which has been idled since July 2013.  We are in the process of permitting the Penn Ridge property for future mine development.

 

The White Oak reportable segment is comprised of two operating segments, WOR Processing and WOR Properties.  WOR Processing includes both the surface operations at White Oak and the equity investment in White Oak.  WOR Properties owns coal reserves acquired from White Oak under lease-back arrangements (Note 6).

 

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Other and Corporate includes marketing and administrative expenses, Alliance Service, Inc. (“ASI”) and its subsidiary, Matrix Design Group, LLC (“Matrix Design”), Alliance Design Group, LLC (“Alliance Design”) (collectively, Matrix Design and Alliance Design are referred to as the “Matrix Group”), ASI’s ownership of aircraft, the Mt. Vernon Transfer Terminal, LLC (“Mt. Vernon”) dock activities, coal brokerage activity, our equity investment in Mid-America Carbonates, LLC, certain activities of Alliance Resource Properties and the Pontiki Coal, LLC mining complex(“Pontiki”), which ceased operations in late November 2013.

 

As a result of the cessation of operations at Pontiki in November 2013, we evaluated the ongoing management of our mining operations and coal sales efforts to ensure that resources were appropriately allocated to maximize our overall results.  Based on this evaluation, we have realigned the management of our operating and marketing teams and changed our reportable segment presentation to reflect this realignment.  Due to the change in our reportable segment presentation in 2014, certain reclassifications of 2013 segment information have been made to conform to the 2014 presentation.  These reclassifications include changes to the Appalachian and Other and Corporate segments.

 

Reportable segment results as of and for the three months ended March 31, 2014 and 2013 are presented below.

 

		Illinois Basin			Appalachia			White Oak			Other and Corporate			Elimination (1)			Consolidated
		(in thousands)
Reportable segment results as of and for the three months ended March 31, 2014 were as follows:
Total revenues (2)		$	396,502		$	137,184		$	3,698		$	7,742		$	(3,088)		$	542,038
Segment Adjusted EBITDA Expense (3)		229,591			85,573			1,391			8,471			(3,088)			321,938
Segment Adjusted EBITDA (4)(5)		163,649			48,870			(3,997)			(668)			-			207,854
Total assets (6)		1,119,868			620,775			343,040			53,404			(1,129)			2,135,958
Capital expenditures (7)		55,709			10,128			1,959			3,068			-			70,864
Reportable segment results as of and for the three months ended March 31, 2013 were as follows:
Total revenues (2)		$	404,823		$	122,359		$	-		$	26,507		$	(5,634)		$	548,055
Segment Adjusted EBITDA Expense (3)		234,145			95,925			101			24,366			(5,634)			348,903
Segment Adjusted EBITDA (4)(5)		167,221			22,957			(4,292)			2,465			-			188,351
Total assets (6)		1,046,513			599,502			272,316			82,646			(1,439)			1,999,538
Capital expenditures (7)		52,031			12,555			16,953			831			-			82,370

 

(1)      The elimination column represents the elimination of intercompany transactions and is primarily comprised of sales from the Matrix Group to our mining operations and coal sales and purchases between mining operations (2013 only).

 

(2)      Revenues included in the Other and Corporate column are primarily attributable to the Matrix Group revenues, Mt. Vernon transloading revenues, administrative service revenues from affiliates, brokerage sales and Pontiki’s coal sales revenue (2013 only).

 

(3)      Segment Adjusted EBITDA Expense includes operating expenses, outside coal purchases and other income. Transportation expenses are excluded as these expenses are passed through to our customers and consequently we do not realize any gain or loss on transportation revenues.  We review Segment Adjusted EBITDA Expense per ton for cost trends.

 

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The following is a reconciliation of consolidated Segment Adjusted EBITDA Expense to operating expenses (excluding depreciation, depletion and amortization) (in thousands):

 

		Three Months Ended
		March 31,
		2014				2013
Segment Adjusted EBITDA Expense		$	321,938			$	348,903
Outside coal purchases		(2		)		(602		)
Other income		306				274
Operating expenses (excluding depreciation, depletion and amortization)		$	322,242			$	348,575

 

(4) Segment Adjusted EBITDA is defined as net income before net interest expense, income taxes, depreciation, depletion and amortization and general and administrative expenses.  Management therefore is able to focus solely on the evaluation of segment operating profitability as it relates to our revenues and operating expenses, which are primarily controlled by our segments.  Consolidated Segment Adjusted EBITDA is reconciled to net income as follows (in thousands):

 

		Three Months Ended
		March 31,
		2014				2013
Consolidated Segment Adjusted EBITDA		$	207,854			$	188,351
General and administrative		(17,435		)		(15,246		)
Depreciation, depletion and amortization		(66,841		)		(64,382		)
Interest expense, net		(7,674		)		(6,484		)
Income tax benefit		-				698
Net income		$	115,904			$	102,937

 

(5)      Includes equity in income (loss) of affiliates for the three months ended March 31, 2014 and 2013 of $(6.3) million and $(4.2) million, respectively, included in the White Oak segment and $0.1 million and $0.3 million, respectively, included in the Other and Corporate segment.

 

(6)      Total assets at March 31, 2014 and 2013 include investments in affiliate of $152.4 million and $113.7 million, respectively, for the White Oak segment and $1.7 million and $1.9 million, respectively, for the Other and Corporate segment.

 

(7)      Capital expenditures shown above for the three months ended March 31, 2014 and 2013, included funding of $1.4 million and $12.1 million, respectively, for the acquisition and development of coal reserves from White Oak (Note 6), which is described as “Payments to affiliate for acquisition and development of coal reserves” in our condensed consolidated statements of cash flow.

 

12.       SUBSEQUENT EVENTS

 

On April 28, 2014, we declared a quarterly distribution for the quarter ended March 31, 2014, of $1.2225 per unit, on all common units outstanding, totaling approximately $77.9 million (which includes our managing general partner’s incentive distributions), payable on May 15, 2014 to all unitholders of record as of May 8, 2014.

 

Other than the event described above and in Note 7, there were no other subsequent events.

 

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ITEM 2.          MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

 

Significant relationships referenced in this management’s discussion and analysis of financial condition and results of operations include the following:

 

·	References to “we,” “us,” “our” or “ARLP Partnership” mean the business and operations of Alliance Resource Partners, L.P., the parent company, as well as its consolidated subsidiaries.
·	References to “ARLP” mean Alliance Resource Partners, L.P., individually as the parent company, and not on a consolidated basis.
·	References to “MGP” mean Alliance Resource Management GP, LLC, the managing general partner of Alliance Resource Partners, L.P., also referred to as our managing general partner.
·	References to “SGP” mean Alliance Resource GP, LLC, the special general partner of Alliance Resource Partners, L.P., also referred to as our special general partner.
·	References to “Intermediate Partnership” mean Alliance Resource Operating Partners, L.P., the intermediate partnership of Alliance Resource Partners, L.P., also referred to as our intermediate partnership.
·	References to “Alliance Coal” mean Alliance Coal, LLC, the holding company for the operations of Alliance Resource Operating Partners, L.P., also referred to as our operating subsidiary.
·	References to “AHGP” mean Alliance Holdings GP, L.P., individually as the parent company, and not on a consolidated basis.
·	References to “AGP” mean Alliance GP, LLC, the general partner of Alliance Holdings GP, L.P.

 

Summary

 

We are a diversified producer and marketer of coal primarily to major United States (“U.S.”) utilities and industrial users. We began mining operations in 1971 and, since then, have grown through acquisitions and internal development to become the third largest coal producer in the eastern U.S. We operate ten underground mining complexes in Illinois, Indiana, Kentucky, Maryland and West Virginia.  We are constructing an additional mine (the “Gibson South mine”) at our southern Indiana Gibson County Coal, LLC (“Gibson County Coal”) mining complex and operate a coal loading terminal on the Ohio River at Mt. Vernon, Indiana.  Incidental production began at the Gibson South mine in April 2014.  Also, we own a preferred equity interest and are making additional equity investments in White Oak Resources LLC (“White Oak”) and are purchasing and funding development of reserves and have constructed and are operating surface facilities at White Oak’s new longwall mining complex in southern Illinois.  As is customary in the coal industry, we have entered into long-term coal supply agreements with many of our customers.

 

We have four reportable segments: Illinois Basin, Appalachia, White Oak and Other and Corporate.  The first two reportable segments correspond to major coal producing regions in the eastern U.S.  Factors similarly affecting financial performance of our operating segments within each of these two reportable segments generally include coal quality, geology, coal marketing opportunities, mining and transportation methods and regulatory issues.  The White Oak segment includes our activities associated with the White Oak longwall Mine No. 1 development project in southern Illinois more fully described below.

 

·                 Illinois Basin reportable segment is comprised of multiple operating segments, including Webster County Coal, LLC’s Dotiki mining complex (“Dotiki”), Gibson County Coal, which includes the Gibson North mine and Gibson South mine, Hopkins County Coal, LLC mining complex, which includes the Elk Creek mine and the Fies property, White County Coal, LLC’s Pattiki mining complex (“Pattiki”), Warrior Coal, LLC’s mining complex (“Warrior”), Sebree Mining, LLC’s mining complex (“Sebree”), which includes the Onton mine, Steamport, LLC and certain undeveloped coal reserves, River View Coal, LLC’s mining complex, CR Services, LLC, and certain properties of Alliance Resource Properties, LLC (“Alliance Resource Properties”), ARP

 

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Sebree, LLC and ARP Sebree South, LLC.  The development of the Gibson South mine is currently underway with incidental production beginning in April 2014.  We are in the process of permitting the Sebree and Fies properties for future mine development.

 

·                 Appalachian reportable segment is comprised of multiple operating segments, including the Mettiki mining complex, the Tunnel Ridge, LLC mining complex (“Tunnel Ridge”), the MC Mining, LLC mining complex (“MC Mining”) and the Penn Ridge Coal, LLC (“Penn Ridge”) property.  The Mettiki mining complex includes Mettiki Coal (WV), LLC’s Mountain View mine, Mettiki Coal, LLC’s preparation plant and a small third-party mining operation which has been idled since July 2013.  We are in the process of permitting the Penn Ridge property for future mine development.

 

·                 White Oak reportable segment is comprised of two operating segments, Alliance WOR Properties, LLC (“WOR Properties”) and Alliance WOR Processing, LLC (“WOR Processing”).  WOR Properties owns reserves acquired from White Oak and is committed to acquiring additional reserves from White Oak under lease-back arrangements.  WOR Properties has also provided, and is continuing to provide, certain funding to White Oak for development of these reserves.  WOR Processing includes both the surface operations at White Oak and the equity investments we are making in White Oak.  The White Oak reportable segment also includes a loan to White Oak from our Intermediate Partnership to construct certain surface facilities. For more information on White Oak, please read “Item 1. Financial Statements (Unaudited) – Note 6. White Oak Transactions” of this Quarterly Report on Form 10-Q.

 

·                 Other and Corporate segment includes marketing and administrative expenses, Alliance Service, Inc. (“ASI”) and its subsidiary, Matrix Design Group, LLC (“Matrix Design”), Alliance Design Group, LLC, ASI’s ownership of aircraft, the Mt. Vernon Transfer Terminal, LLC (“Mt. Vernon”) dock activities, coal brokerage activity, our equity investment in Mid-America Carbonates, LLC (“MAC”), certain activities of Alliance Resource Properties and the Pontiki Coal, LLC mining complex (“Pontiki”) which ceased operations in late November 2013.

 

As a result of a change in our reportable segments in 2014, certain reclassifications of 2013 segment information have been made to conform to the 2014 presentation.  These reclassifications include changes to the Appalachian reportable segment and Other and Corporate segment.

 

Three Months Ended March 31, 2014 Compared to Three Months Ended March 31, 2013

 

We reported record net income of $115.9 million for the three months ended March 31, 2014 (“2014 Quarter”) compared to $102.9 million for the three months ended March 31, 2013 (“2013 Quarter”).  This increase of $13.0 million was principally due to lower operating expenses during the 2014 Quarter, primarily as a result of increased longwall production and improved recoveries at our Tunnel Ridge mine and the absence of higher cost production at our Pontiki mine.  We also produced a record 10.3 million tons in the 2014 Quarter compared to 9.8 million tons in the 2013 Quarter.  The increase in tons produced resulted from increased production at our Tunnel Ridge mine, increased production in the new Excel No. 4 mining area at our MC Mining mine and improved geological conditions at our Dotiki mine.  Although we had record tons produced, coal sales volumes decreased to 9.5 million tons sold in the 2014 Quarter compared to 9.7 million tons sold in the 2013 Quarter primarily due to weather-related transportation disruptions at our Warrior, Gibson North and Pattiki mines.

 

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		Three Months Ended March 31,
		2014		2013		2014		2013
		(in thousands)				(per ton sold)
Tons sold		9,495		9,698		N/A		N/A
Tons produced		10,253		9,819		N/A		N/A
Coal sales		$525,545		$534,509		$55.35		$55.12
Operating expenses and outside coal purchases		$322,244		$349,177		$33.94		$36.01

 

Coal sales.  Coal sales for the 2014 Quarter decreased 1.7% to $525.5 million from $534.5 million for the 2013 Quarter.  The decrease of $9.0 million in coal sales reflected the impact of lower tons sold (reducing coal sales by $11.2 million), offset partially by higher average coal sales prices (contributing $2.2 million in additional coal sales).  Average coal sales price increased slightly to $55.35 per ton in the 2014 Quarter as compared to $55.12 per ton sold in the 2013 Quarter, primarily as a result of higher priced coal sales at our Mettiki mine.

 

Operating expenses and outside coal purchases.  Operating expenses and outside coal purchases combined decreased 7.7% to $322.2 million for the 2014 Quarter from $349.2 million for the 2013 Quarter, primarily due to the favorable impact of increased lower-cost production at our Tunnel Ridge mine, reduced cost per ton at our Dotiki and MC Mining mines, lower coal sales volumes and the absence of higher cost production at our Pontiki mine discussed above.  On a per ton basis, operating expenses and outside coal purchases decreased 5.7% to $33.94 per ton sold.  Operating expenses were impacted by various factors in addition to the impact of record production volumes.  The most significantly impacted expenses are discussed below:

 

·                 Labor and benefit expenses per ton produced, excluding workers’ compensation, decreased 5.1% to $11.08 per ton in the 2014 Quarter from $11.67 per ton in the 2013 Quarter.  This decrease of $0.59 per ton was primarily attributable to lower labor cost per ton resulting from increased coal production and improved recoveries discussed above;

 

·                 Workers’ compensation expenses per ton produced decreased 37.5% to $0.45 per ton in the 2014 Quarter from $0.72 per ton in the 2013 Quarter.  The decrease of $0.27 per ton produced resulted primarily from favorable claims trends;

 

·                 Materials and supplies expenses per ton produced decreased 4.0% to $10.95 per ton in the 2014 Quarter from $11.41 per ton in the 2013 Quarter.  The decrease of $0.46 per ton produced resulted primarily from increased coal production discussed above and a decrease in cost for certain products and services, primarily contract labor used in the mining process (decrease of $0.42 per ton) and roof support expenses per ton (decrease of $0.10 per ton), partially offset by an increase in power and fuel used in the mining process (increase of $0.15 per ton);

 

·                 Maintenance expenses per ton produced decreased 4.8% to $3.74 per ton in the 2014 Quarter from $3.93 per ton in the 2013 Quarter.  The decrease of $0.19 per ton produced was primarily from the benefits of newer equipment and increased production at our Tunnel Ridge mine and increased coal production and improved recoveries at certain locations as discussed above; and

 

·                 Contract mining expenses decreased $2.0 million in the 2014 Quarter compared to the 2013 Quarter.  The decrease reflects lower production from a third-party mining operation in our Appalachian region due to reduced metallurgical coal export market opportunities.

 

Other sales and operating revenues.  Other sales and operating revenues are principally comprised of Mt. Vernon transloading revenues, Matrix Design sales, throughput fees received from White Oak and other outside services and administrative services revenue from affiliates.  Other sales and

 

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operating revenues increased to $10.5 million in the 2014 Quarter from $6.6 million in the 2013 Quarter.  The increase of $3.9 million was primarily due to increased Matrix Design sales and White Oak throughput fees.

 

General and administrative.  General and administrative expenses for the 2014 Quarter increased to $17.4 million compared to $15.2 million in the 2013 Quarter.  The increase of $2.2 million was primarily due to higher incentive compensation expenses.

 

Depreciation, depletion and amortization.  Depreciation, depletion and amortization expense increased to $66.8 million for the 2014 Quarter from $64.4 million for the 2013 Quarter.  The increase of $2.4 million was attributable to increased production levels mentioned above, as well as capital expenditures related to production expansion and infrastructure investments at various operations.

 

Interest expense.  Interest expense, net of capitalized interest, increased to $8.1 million for the 2014 Quarter from $6.6 million for the 2013 Quarter.  The increase of $1.5 million in the 2014 Quarter was principally attributable to lower capitalized interest on our equity investment in White Oak.  Interest payable under our term loan and revolving credit facility is discussed below under “–Debt Obligations.”

 

Transportation revenues and expenses.  Transportation revenues and expenses were $6.0 million and $6.9 million for the 2014 and 2013 Quarters, respectively.  The decrease of $0.9 million was primarily attributable to decreased tonnage for which we arrange transportation at certain mines, partially offset by an increase in average transportation rates in the 2014 Quarter.  The cost of transportation services are passed through to our customers.  Consequently, we do not realize any gain or loss on transportation revenues.

 

Equity in loss of affiliates, net.  Equity in loss of affiliates, net includes our equity investments in MAC and White Oak.  For the 2014 Quarter, equity in loss of affiliates was $6.2 million compared to $3.9 million for the 2013 Quarter, which was primarily attributable to losses allocated to us due to our equity investment in White Oak.

 

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Segment Adjusted EBITDA.  Our 2014 Quarter Segment Adjusted EBITDA increased $19.5 million, or 10.4%, to a record $207.9 million from the 2013 Quarter Segment Adjusted EBITDA of $188.4 million.  Segment Adjusted EBITDA, tons sold, coal sales, other sales and operating revenues and Segment Adjusted EBITDA Expense by segment are (in thousands):

 

		Three Months Ended
		March 31,
		2014			2013					Increase/(Decrease)
Segment Adjusted EBITDA
Illinois Basin		$	163,649		$	167,221				$	(3,572)		(2.1)%
Appalachia		48,870			22,957					25,913			(1)
White Oak		(3,997)			(4,292)					295			6.9%
Other and Corporate		(668)			2,465					(3,133)			(1)
Elimination		-			-					-			-
Total Segment Adjusted EBITDA (2)		$	207,854		$	188,351				$	19,503		10.4%
Tons sold
Illinois Basin		7,482			7,706					(224)			(2.9)%
Appalachia		2,013			1,783					230			12.9%
White Oak		-			-					-			-
Other and Corporate		-			242					(242)			(1)
Elimination		-			(33)					33			(1)
Total tons sold		9,495			9,698					(203)			(2.1)%
Coal sales
Illinois Basin		$	392,254		$		400,320			$	(8,066)		(2.0)%
Appalachia		133,291			117,744					15,547			13.2%
White Oak		-			-					-			-
Other and Corporate		-			18,522					(18,522)			(1)
Elimination		-			(2,077)					2,077			(1)
Total coal sales		$	525,545		$	534,509				$	(8,964)		(1.7)%
Other sales and operating revenues
Illinois Basin		$	986		$	1,045				$	(59)		(5.6)%
Appalachia		1,151			1,139					12			1.1%
White Oak		3,698			-					3,698			-
Other and Corporate		7,741			7,985					(244)			(3.1)%
Elimination		(3,088)			(3,557)					469			13.2%
Total other sales and operating revenues		$	10,488		$	6,612				$	3,876		58.6%
Segment Adjusted EBITDA Expense
Illinois Basin		$	229,591		$			234,145		$	(4,554)		(1.9)%
Appalachia		85,573			95,925					(10,352)			(10.8)%
White Oak		1,391			101					1,290			(1)
Other and Corporate		8,471			24,366					(15,895)			(65.2)%
Elimination		(3,088)			(5,634)					2,546			45.2%
Total Segment Adjusted EBITDA Expense (3)		$	321,938		$	348,903				$	(26,965)		(7.7)%

 

(1)  Percentage change was greater than or equal to 100%.

 

(2)  Segment Adjusted EBITDA (a non-GAAP financial measure) is defined as net income before net interest expense, income taxes, depreciation, depletion and amortization, and general and administrative expenses.  Segment Adjusted EBITDA is a key component of consolidated EBITDA,

 

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