Press Releases

TULSA, Okla.--(BUSINESS WIRE)-- Alliance Resource Partners, L.P. (NASDAQ: ARLP) today reported financial and operating results for the quarter ended June 30, 2015 (the "2015 Quarter"). Reflecting higher other sales and operating revenues, total revenues increased to a record $604.7 million compared to $598.6 million for the quarter ended June 30, 2014 (the "2014 Quarter"). Although total revenue increased, higher operating expenses and equity in loss of affiliates from White Oak led to lower EBITDA, which decreased $30.7 million to $182.4 million for the 2015 Quarter. These factors and increased depreciation, depletion and amortization expense contributed to lower net income for the 2015 Quarter, which decreased 31.1% compared to the 2014 Quarter to $94.9 million, or $0.76 per basic and diluted limited partner unit. (For a definition of EBITDA and related reconciliations to comparable GAAP financial measures, please see the end of this release.)

ARLP also announced that the Board of Directors of its managing general partner (the "Board") increased the cash distribution to unitholders for the 2015 Quarter to $0.675 per unit (an annualized rate of $2.70 per unit), payable on August 14, 2015 to all unitholders of record as of the close of trading on August 7, 2015. The announced distribution represents an 8.0% increase over the cash distribution of $0.625 per unit for the 2014 Quarter and a 1.9% increase over the cash distribution of $0.6625 per unit for the quarter ended March 31, 2015 (the "Sequential Quarter").

"ARLP delivered another solid performance in the 2015 Quarter," said Joseph W. Craft III, President and Chief Executive Officer. "Key to this performance was shipping record coal sales volumes during the quarter, which contributed to record quarterly revenues. Coal inventories fell by approximately 962,000 tons during the 2015 Quarter, exceeding our expectations. Operations also performed well and finished the first half of this year with the best safety performance in ARLP’s history. Excluding the results from our preferred equity investments in White Oak, the 2015 Quarter and year-to-date financial results came in as we expected. As previously announced, we reached agreement to acquire the remaining equity interests in White Oak not already owned by ARLP and are on track to close this transaction later this week. We believe acquiring full ownership of White Oak and assuming operating and marketing control of the White Oak Mine No. 1 provides ARLP with significant strategic advantages in the Illinois Basin and will benefit us in the long term."

Mr. Craft added, "Based on ARLP’s quarterly results, our strong 1.71x distribution coverage ratio and confidence in ARLP’s outlook, the Board announced today an increase in unitholder distributions for the twenty-ninth consecutive quarter."

Consolidated Financial Results

Three Months Ended June 30, 2015 Compared to Three Months Ended June 30, 2014

Increased total revenues for the 2015 Quarter reflect higher other sales and operating revenues of $29.7 million, which climbed $12.1 million compared to the 2014 Quarter, partially offset by lower coal sales revenues, which decreased $7.9 million to $567.3 million. Other sales and operating revenues increased primarily due to higher surface facility services and coal royalties from ARLP’s investments related to the White Oak Mine No. 1, which rose $14.5 million compared to the 2014 Quarter. Despite record coal sales volumes of 10.5 million tons, coal sales revenues for the 2015 Quarter declined slightly to $567.3 million as a result of lower average coal sales prices of $54.13 per ton sold, a decrease of 2.5% compared to the 2014 Quarter.

Compared to the 2014 Quarter, operating expenses rose 6.3% to $375.1 million, primarily as a result of higher sales-related expenses due to increased coal sales volumes in the 2015 Quarter, as well as non-recurring benefits realized in the 2014 Quarter from a gain of $4.4 million recognized on the sale of assets at the Pontiki mine and a $7.0 million insurance settlement related to an adverse geological event in 2013 at the Onton mine. These comparative factors also contributed to higher Segment Adjusted EBITDA Expense per ton of $35.77 in the 2015 Quarter, an increase of 5.1% compared to the 2014 Quarter.

Reflecting ARLP’s decision to reduce unit shifts in response to market conditions, coal production volumes decreased to 9.5 million tons in the 2015 Quarter, a reduction of 2.5% compared to the 2014 Quarter.

Depreciation, depletion and amortization increased $12.7 million to $79.8 million in the 2015 Quarter compared to the 2014 Quarter, due to the previously announced reduction of the economic mine life at our Hopkins mine, which is expected to close in early 2016, increased production at the Gibson South mine, which commenced initial production in April 2014, amortization of coal supply agreements acquired in December 2014 and capital expenditures related to infrastructure investments at various operations. General and administrative expenses decreased $2.2 million to $17.5 million in the 2015 Quarter, primarily as a result of lower incentive compensation expenses.

Total net equity in loss of affiliates increased to $22.1 million for the 2015 Quarter, compared to a loss of $7.4 million for the 2014 Quarter, primarily due to low coal sales price realizations and higher expenses reflecting White Oak’s continued ramp up of longwall production following the commencement of operations in late 2014. As discussed herein, we have reached an agreement with White Oak to acquire all equity interests not currently owned by ARLP and will begin to account for White Oak on a consolidated basis after the anticipated July 31, 2015 closing of the transaction.

Six Months Ended June 30, 2015 Compared to Six Months Ended June 30, 2014

For the six months ended June 30, 2015 (the "2015 Period"), increases at the Tunnel Ridge and Gibson South mines led to a record 20.0 million tons sold and produced, slightly above sales and production volumes compared to the six months ended June 30, 2014 (the "2014 Period"). Total revenues rose 2.2% to a record $1.2 billion in the 2015 Period on the strength of higher other sales and operating revenues, primarily due to increased surface facility services and coal royalties from White Oak. Coal sales revenues declined slightly to $1.1 billion for the 2015 Period as average coal sales prices decreased approximately 2.0% to $54.30 per ton sold. Increased operating expenses and equity in loss of affiliates drove EBITDA for the 2015 Period down 7.2% to $374.5 million and, along with higher depreciation, depletion and amortization, contributed to lower net income of $201.3 million, or $1.68 of net income per basic and diluted limited partner unit, a decrease of 20.6% compared to the 2014 Period.

Regional Results and Analysis

Higher coal sales volumes primarily from the Tunnel Ridge and Gibson South mines led to a record 10.5 million total tons sold in the 2015 Quarter, an increase of 1.1% and 10.3% over the 2014 and Sequential Quarters, respectively. Strong sales performance from the Tunnel Ridge longwall operation drove coal sales tons for the 2015 Quarter higher in Appalachia by 16.8% and 15.5% compared to the 2014 and Sequential Quarters, respectively. Compared to the 2014 Quarter, coal sales volumes decreased 3.4% in the Illinois Basin due primarily to lower sales at our Warrior mine as it continues to transition to a new mining area, shift reductions at our Gibson North mine and an inventory build at our Dotiki and River View mines, offset in part by strong performance at Gibson South reflecting increased production at the mine since commencement of initial production in April 2014. Coal sales volumes in the Illinois Basin increased from the Sequential Quarter primarily as a result of strong performance at the Gibson South mine and increased sales from coal inventories across the region.

Reflecting current market conditions, ARLP's total coal sales price per ton in the 2015 Quarter decreased in line with expectations compared to both the 2014 and Sequential Quarters. Lower coal sales prices in Appalachia also reflect the impact at Tunnel Ridge of a previously disclosed customer breach of an above-market coal supply agreement, which is now the subject of litigation.

Total Segment Adjusted EBITDA Expense per ton in the 2015 Quarter increased 5.1% compared to the 2014 Quarter, primarily as a result of increased expenses per ton in the Appalachian region and the previously discussed insurance settlement at Onton and gain on sale of assets at Pontiki benefiting the 2014 Quarter. In Appalachia, Segment Adjusted EBITDA Expense per ton increased 8.3% compared to the 2014 Quarter primarily due to lower recoveries across the region. Compared to the Sequential Quarter, Segment Adjusted EBITDA Expense per ton in Appalachia increased 5.1% as a result of lower recoveries and increased longwall move days at both our Mettiki and Tunnel Ridge mines. In the Illinois Basin, Segment Adjusted EBITDA Expense per ton decreased slightly in the 2015 Quarter compared to both the 2014 and Sequential Quarters primarily due to increased production from our Gibson South mine and decreased workers’ compensation and materials and supplies expenses at various locations. Compared to the 2014 Quarter, these decreases in the Illinois Basin were offset in part by the Onton insurance settlement in 2014 and fewer work days due to the timing of miner vacations.

Outlook

Commenting on ARLP’s current outlook for the rest of the year, Mr. Craft said, "Most of our coal industry counterparts are under extreme duress, particularly those with high leverage and significant exposure to the metallurgical coal markets. Thermal coal demand in the domestic utility market has also fallen this year primarily due to lower natural gas prices and a weaker export market. We believe, however, that market demand is beginning to stabilize and recent market weakness is causing a supply response. Total coal production has declined from the Sequential Quarter by 13.5% in the Illinois Basin and 15.0% in the northern Appalachian markets. We expect further supply reductions, which will continue to improve the oversupply situation in those regions."

Mr. Craft added, "While we have also been impacted by reduced demand, ARLP continues to distinguish itself from others in our industry. Our sales contract position, strong balance sheet, low-cost operations and strategy to focus on the domestic utility market have allowed us to perform well and increase distributable cash flow through the first half of the year."

ARLP currently anticipates closing the acquisition of the remaining equity interests in White Oak within the week. ARLP continues to expect full year EBITDA and net income will be within the range of prior guidance and, once closing has occurred, we will provide a full update to 2015 guidance to reflect consolidation of the White Oak Mine No. 1 and termination of the current coal royalty and surface facilities services agreements and the preferred equity interests related to White Oak.

A conference call regarding ARLP’s 2015 Quarter financial results is scheduled for Tuesday, July 28, 2015 at 9:00 a.m. Eastern. To participate in the conference call, dial (855) 793-3259 and provide conference number 85117094. International callers should dial (631) 485-4928 and provide the same conference number. Investors may also listen to the call via the "investor information" section of ARLP’s website at http://www.arlp.com.

An audio replay of the conference call will be available for approximately one week. To access the audio replay, dial (855) 859-2056 and provide conference number 85117094. International callers should dial (404) 537-3406 and provide the same conference number.

This announcement is intended to be a qualified notice under Treasury Regulation Section 1.1446-4(b), with 100% of the partnership’s distributions to foreign investors attributable to income that is effectively connected with a United States trade or business. Accordingly, ARLP’s distributions to foreign investors are subject to federal income tax withholding at the highest applicable tax rate.

About Alliance Resource Partners, L.P.

ARLP is a diversified producer and marketer of coal to major United States utilities and industrial users. ARLP, the nation’s first publicly traded master limited partnership involved in the production and marketing of coal, is currently the third largest coal producer in the eastern United States with mining operations in the Illinois Basin and Appalachian coal producing regions.

ARLP currently operates ten mining complexes in Illinois, Indiana, Kentucky, Maryland and West Virginia. ARLP has also made equity investments in White Oak and purchased reserves and operates surface facilities related to the White Oak Mine No. 1. ARLP has reached an agreement to acquire all of the equity interests in White Oak not currently owned by ARLP. In addition, ARLP operates a coal loading terminal on the Ohio River at Mount Vernon, Indiana.

News, unit prices and additional information about ARLP, including filings with the Securities and Exchange Commission, are available at http://www.arlp.com. For more information, contact the investor relations department of Alliance Resource Partners, L.P. at (918) 295-7674 or via e-mail at investorrelations@arlp.com.

The statements and projections used throughout this release are based on current expectations. These statements and projections are forward-looking, and actual results may differ materially. At the end of this release, we have included more information regarding business risks that could affect our results.

FORWARD-LOOKING STATEMENTS:With the exception of historical matters, any matters discussed in this press release are forward-looking statements that involve risks and uncertainties that could cause actual results to differ materially from projected results.These risks, uncertainties and contingencies include, but are not limited to, the following: changes in competition in coal markets and our ability to respond to such changes; changes in coal prices, which could affect our operating results and cash flows; risks associated with the expansion of our operations and properties; legislation, regulations, and court decisions and interpretations thereof, including those relating to the environment, mining, miner health and safety and health care; deregulation of the electric utility industry or the effects of any adverse change in the coal industry, electric utility industry, or general economic conditions; dependence on significant customer contracts, including renewing customer contracts upon expiration of existing contracts; changing global economic conditions or in industries in which our customers operate; liquidity constraints, including those resulting from any future unavailability of financing; customer bankruptcies, cancellations or breaches to existing contracts, or other failures to perform; customer delays, failure to take coal under contracts or defaults in making payments; adjustments made in price, volume or terms to existing coal supply agreements; fluctuations in coal demand, prices and availability; our productivity levels and margins earned on our coal sales; changes in raw material costs; changes in the availability of skilled labor; our ability to maintain satisfactory relations with our employees; increases in labor costs, adverse changes in work rules, or cash payments or projections associated with post-mine reclamation and workers′ compensation claims; increases in transportation costs and risk of transportation delays or interruptions; operational interruptions due to geologic, permitting, labor, weather-related or other factors; risks associated with major mine-related accidents, such as mine fires, or interruptions; results of litigation, including claims not yet asserted; difficulty maintaining our surety bonds for mine reclamation as well as workers′ compensation and black lung benefits; difficulty in making accurate assumptions and projections regarding pension, black lung benefits and other post-retirement benefit liabilities; the coal industry’s share of electricity generation, including as a result of environmental concerns related to coal mining and combustion and the cost and perceived benefits of other sources of electricity, such as natural gas, nuclear energy and renewable fuels; uncertainties in estimating and replacing our coal reserves; a loss or reduction of benefits from certain tax deductions and credits; difficulty obtaining commercial property insurance, and risks associated with our participation (excluding any applicable deductible) in the commercial insurance property program; and difficulty in making accurate assumptions and projections regarding future revenues and costs associated with equity investments in companies we do not control.

Additional information concerning these and other factors can be found in ARLP’s public periodic filings with the Securities and Exchange Commission ("SEC"), including ARLP’s Annual Report on Form 10-K for the year ended December 31, 2014, filed on February 27, 2015 with the SEC.Except as required by applicable securities laws, ARLP does not intend to update its forward-looking statements.

Reconciliation of GAAP "Net Income" to non-GAAP "EBITDA" and non-GAAP "Distributable Cash Flow" (in thousands).

EBITDA is defined as net income (prior to the allocation of noncontrolling interest) before net interest expense, income taxes and depreciation, depletion and amortization. EBITDA is used as a supplemental financial measure by our management and by external users of our financial statements such as investors, commercial banks, research analysts and others, to assess:

• the financial performance of our assets without regard to financing methods, capital structure or historical cost basis;
• the ability of our assets to generate cash sufficient to pay interest costs and support our indebtedness;
• our operating performance and return on investment as compared to those of other companies in the coal energy sector, without regard to financing or capital structures; and
• the viability of acquisitions and capital expenditure projects and the overall rates of return on alternative investment opportunities.

Distributable cash flow ("DCF") is defined as EBITDA excluding equity in income or loss of affiliates, interest expense (before capitalized interest), interest income, income taxes and estimated maintenance capital expenditures. Distribution coverage ratio ("DCR") is defined as DCF divided by distributions paid to partners. DCF and DCR are used as supplemental financial measures by our management and by external users of our financial statements, such as investors, commercial banks, research analysts and others, to assess:

• the cash flows generated by our assets (prior to the establishment of any retained cash reserves by the general partner) to fund the cash distributions we expect to pay to unitholders;
• our success in providing a cash return on investment and whether or not the Partnership is generating cash flow at a level that can sustain or support an increase in its quarterly distribution rates;
• the yield of our units, which is a quantitative standard used throughout the investment community with respect to publicly-traded partnerships as the value of a unit is generally determined by a unit’s yield (which in turn is based on the amount of cash distributions the entity pays to a unitholder).

EBITDA and DCF should not be considered as alternatives to net income, income from operations, cash flows from operating activities or any other measure of financial performance presented in accordance with generally accepted accounting principles. EBITDA and DCF are not intended to represent cash flow and do not represent the measure of cash available for distribution. Our method of computing EBITDA, DCF and DCR may not be the same method used to compute similar measures reported by other companies, or EBITDA, DCF and DCR may be computed differently by us in different contexts (i.e. public reporting versus computation under financing agreements).

⁽¹⁾ Our maintenance capital expenditures, as defined under the terms of our partnership agreement, are those capital expenditures required to maintain, over the long-term, the operating capacity of our capital assets. We estimate maintenance capital expenditures on an annual basis based upon a five-year planning horizon. For the 2015 planning horizon, average annual estimated maintenance capital expenditures are assumed to be $4.96 per produced ton compared to the estimated $5.90 per produced ton in 2014. Our current per ton estimate of average annual maintenance capital expenditures decreased from our initial estimate of $5.55 per ton as a result of optimization efforts across all of our operations. Our actual maintenance capital expenditures vary depending on various factors, including maintenance schedules and timing of capital projects, among others. We annually disclose our actual maintenance capital expenditures in our Form 10-K filed with the Securities and Exchange Commission.

Reconciliation of GAAP "Operating Expenses" to non-GAAP "Segment Adjusted EBITDA Expense per ton" and Reconciliation of non-GAAP "EBITDA" to "Segment Adjusted EBITDA per ton" (in thousands, except per ton data).

Segment Adjusted EBITDA Expense per ton includes operating expenses, outside coal purchases and other income divided by tons sold. Transportation expenses are excluded as these expenses are passed through to our customers and, consequently, we do not realize any margin on transportation revenues. Segment Adjusted EBITDA Expense is used as a supplemental financial measure by our management to assess the operating performance of our segments. Segment Adjusted EBITDA Expense is a key component of EBITDA in addition to coal sales and other sales and operating revenues. The exclusion of corporate general and administrative expenses from Segment Adjusted EBITDA Expense allows management to focus solely on the evaluation of segment operating performance as it primarily relates to our operating expenses. Outside coal purchases are included in Segment Adjusted EBITDA Expense because tons sold and coal sales include sales from outside coal purchases.

Segment Adjusted EBITDA per ton is defined as net income (prior to the allocation of noncontrolling interest) before net interest expense, income taxes, depreciation, depletion and amortization and general and administrative expenses divided by tons sold. Segment Adjusted EBITDA removes the impact of general and administrative expenses from EBITDA (discussed above) to allow management to focus solely on the evaluation of segment operating performance.

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Alliance Resource Partners, L.P.
Brian L. Cantrell, 918-295-7673

Source: Alliance Resource Partners, L.P.