Alliance Resource Partners, L.P. Reports Record Quarterly Revenues and EBITDA; Increases Quarterly Cash Distribution 3.7% to $1.0625 Per Unit; and Updates 2012 Guidance
TULSA, Okla.--(BUSINESS WIRE)-- Alliance Resource Partners, L.P. (ARLP) today reported financial results for the quarter ended June 30, 2012 (the "2012 Quarter"). Led by record coal sales volumes and pricing, revenues increased 15.7% to a record $529.9 million and EBITDA climbed 6.0% to a record $155.5 million, each as compared to the quarter ended June 30, 2011 (the "2011 Quarter). Compared to the 2011 Quarter, net income declined 2.8% to $95.5 million, or $1.83 per basic and diluted limited partner unit due to anticipated increases in depreciation, depletion and amortization expense and the pass through of losses related to investments in White Oak Resources, LLC (White Oak). (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 increased the cash distribution to unitholders for the 2012 Quarter to $1.0625 per unit (an annualized rate of $4.25 per unit), payable on August 14, 2012 to all unitholders of record as of the close of trading on August 7, 2012. The announced distribution represents a 15.2% increase over the cash distribution of $0.9225 per unit for the 2011 Quarter and a 3.7% increase over the cash distribution of $1.025 per unit for the first quarter of 2012 (the Sequential Quarter).
"ARLPs operating strength, quality customer relationships and solid contract position allowed us to overcome challenging market conditions and deliver another quarter of excellent results to our unitholders," said Joseph W. Craft III, President and Chief Executive Officer. "In addition to posting record EBITDA, sales volumes and revenue, our teams accomplishments during the 2012 Quarter continued to strengthen ARLPs long-term growth prospects. Operationally, we commenced longwall operations in mid-May at our Tunnel Ridge mine, completed the acquisition of the Onton No. 9 mine and continued to make progress at the Gibson South and White Oak mine development projects. On the sales side, we continued to execute ARLPs strategy of securing long-term commitments for our production. To that end, we recently reached agreement for the sale of approximately 5.6 million tons over a six-year period. Since the beginning of the year, we have now made new coal sales commitments of 27 million tons, plus or minus 10% depending on customer nominations, for deliveries through 2018. Financially, we improved our liquidity by approximately $500 million by entering into new revolving credit and term loan facilities. These accomplishments continue to position ARLP for long-term growth giving our Board the confidence to again provide our unitholders with an attractive distribution increase for the seventeenth consecutive quarter."
Consolidated Financial Results
Three Months Ended June 30, 2012 Compared to Three Months Ended June 30, 2011
Reflecting record sales volumes and pricing, coal sales revenues rose to $512.5 million in the 2012 Quarter, an increase of 15.8% compared to the 2011 Quarter. Improved price realizations, particularly in the Illinois Basin and Northern Appalachia, drove total average coal sales prices higher in the 2012 Quarter to a record $59.17 per ton sold, a 5.5% increase compared to the 2011 Quarter. Higher sales volumes in the Illinois Basin and Northern Appalachia, particularly at the Warrior and Tunnel Ridge mines and the newly acquired Onton mine, as well as increased brokerage sales volumes, pushed coal sales volumes up 9.8% in the 2012 Quarter to a record 8.7 million tons.
The increases at Warrior, Tunnel Ridge and Onton also contributed to higher coal production of 8.2 million tons in the 2012 Quarter, an increase of 8.6% compared to the 2011 Quarter. These higher coal sales and production volumes drove operating expenses in the 2012 Quarter higher to $334.6 million, an increase of 17.8% compared to the 2011 Quarter.
Outside coal purchases increased $10.3 million to $16.2 million in the 2012 Quarter compared to the 2011 Quarter, primarily as a result of increased brokerage coal sales volumes and higher cost per ton of coal purchased. General and administrative expenses increased $3.1 million to $16.1 million in the 2012 Quarter compared to the 2011 Quarter, primarily as a result of higher compensation-related expenses and other professional services. Depreciation, depletion and amortization increased $13.0 million to $52.1 million in the 2012 Quarter compared to the 2011 Quarter, primarily as a result of the start-up of longwall production at the Tunnel Ridge mine, the addition of the Onton mine and capital expenditures related to infrastructure improvements at various other operations.
As anticipated, ARLPs financial results for the 2012 Quarter were negatively impacted by losses related to White Oaks development of its Mine No.1. Our preferred equity investment in White Oak requires ARLP to record substantially all of White Oaks income and losses until we achieve our contractual preferred return. As a result, net equity in loss of affiliates in the 2012 Quarter primarily reflects the pass through of approximately $4.6 million of losses related to White Oaks mine development activities.
Six Months Ended June 30, 2012 Compared to Six Months Ended June 30, 2011
For the six months ended June 30, 2012 (the 2012 Period), increases at the River View and Tunnel Ridge mines and the acquisition of the Onton mine in the 2012 Quarter led to record production and sales volumes as tons produced climbed 6.0% and tons sold increased 6.8%, compared to the six months ended June 30, 2011 (the 2011 Period). Higher coal sales volumes and increased average coal sales prices, which rose $2.08 per ton sold, combined to drive 2012 Period revenues to a record $973.5 million, an increase of 10.5% compared to the 2011 Period. Offsetting these increases, higher operating costs and depreciation, depletion and amortization, and the pass through of losses related to the White Oak development project discussed above, as well as reduced sales into the metallurgical export markets during the 2012 Period led to lower EBITDA and net income. EBITDA for the 2012 Period was comparable to the 2011 Period, falling slightly to $287.0 million, while net income declined 7.8% to $178.4 million, or $3.36 per basic and diluted limited partner unit.
Regional Results and Analysis
|(in millions, except per ton data)||
|Coal sales price per ton (1)||$||53.22||$||50.10||6.2||%||$||51.91||2.5||%|
|Segment Adjusted EBITDA Expense per ton (2)||$||32.81||$||30.50||7.6||%||$||30.95||6.0||%|
|Segment Adjusted EBITDA (2)||$||142.7||$||124.2||14.9||%||$||136.9||4.2||%|
|Coal sales price per ton (1)||$||80.73||$||80.66||0.1||%||$||80.48||0.3||%|
|Segment Adjusted EBITDA Expense per ton (2)||$||62.10||$||55.85||11.2||%||$||60.44||2.7||%|
|Segment Adjusted EBITDA (2)||$||9.2||$||17.6||(47.7||)%||$||10.2||(9.8||)%|
|Coal sales price per ton (1)||$||85.35||$||79.92||6.8||%||$||62.06||37.5||%|
Segment Adjusted EBITDA Expense per ton (2)
|Segment Adjusted EBITDA (2)||$||21.2||$||15.6||35.9||%||$||0.3||N/M(4)|
|Coal sales price per ton (1)||$||59.17||$||56.08||5.5||%||$||54.99||7.6||%|
|Segment Adjusted EBITDA Expense per ton (2)||$||40.23||$||36.70||9.6||%||$||36.80||9.3||%|
|Segment Adjusted EBITDA (2)||$||171.6||$||159.7||7.5||%||$||145.7||17.8||%|
(1) Sales price per ton is defined as total coal sales divided by total
(2) For definitions of Segment Adjusted EBITDA expense per ton and Segment Adjusted EBITDA and related reconciliations to comparable GAAP financial measures, please see the end of this release.
(3) Total includes White Oak, other, corporate and eliminations.
(4) Not meaningful, percentage change greater than 100%.
Reflecting higher Illinois Basin, Northern Appalachia and brokerage sales volumes, ARLP sold a record 8.7 million tons of coal in the 2012 Quarter, an increase of 9.8% over the 2011 Quarter. Coal sales volumes in the Illinois Basin increased from the 2011 and Sequential Quarters, primarily as a result of strong sales and production performance from the Warrior mine and the addition of the Onton mine. In Central Appalachia, lower coal sales volumes compared to the 2011 Quarter reflect the loss of a production unit at the Pontiki mine in the third quarter of 2011 and, compared to the Sequential Quarter, the loss of a production unit during the 2012 Quarter at the MC Mining mine, each due to regulatory action. Coal sales volumes in Northern Appalachia increased from the 2011 and Sequential Quarters reflecting the start-up of longwall production at the Tunnel Ridge mine in May 2012. Sequentially, Northern Appalachia also benefited from higher export sales as tons that had been deferred from the first quarter of 2012 were shipped from the Mettiki mining complex during the 2012 Quarter.
Total coal inventory declined by approximately 243,000 tons during the 2012 Quarter to approximately 822,000 tons. ARLP continues to anticipate coal inventories will trend lower throughout the balance of this year.
Compared to the 2011 Quarter, ARLP continued to benefit from improved contract pricing, particularly in the Illinois Basin and Northern Appalachia, as total average coal sales price increased 5.5% to $59.17 per ton sold in the 2012 Quarter. Sequentially, total coal sales prices increased 7.6% due primarily to the previously mentioned higher priced export shipments in the 2012 Quarter.
Total Segment Adjusted EBITDA Expense per ton in the 2012 Quarter increased 9.6% compared to the 2011 Quarter, reflecting the previously discussed increases in operating expenses. Compared to the Sequential Quarter, Segment Adjusted EBITDA Expense per ton in the 2012 Quarter was impacted by fewer work days due to traditional miner vacations in all of ARLPs operating regions. In the Illinois Basin, lower coal recoveries at the River View mine, difficult mining conditions at the Dotiki mine related to its transition into the West Kentucky No. 13 coal seam and the addition of the Onton No. 9 mine, contributed to higher Segment Adjusted EBITDA Expense per ton in the 2012 Quarter. In Central Appalachia, the impact of the loss of a production unit at both the Pontiki and MC Mining mines due to regulatory action, offset in part by improved coal recoveries, contributed to higher Segment Adjusted EBITDA Expense per ton in the 2012 Quarter. In Northern Appalachia, higher Segment Adjusted EBITDA Expense per ton reflects increased cost per ton of coal purchased by the Mettiki complex, higher cost per ton of initial longwall production at the Tunnel Ridge mine, as well as the impact of difficult mining conditions at the Mountain View mine. (For a definition of Segment Adjusted EBITDA and Segment Adjusted EBITDA Expense per ton and related reconciliations to comparable GAAP financial measures, please see the end of this release).
Commenting on ARLPs outlook Mr. Craft continued, "The first half of 2012 has been an extremely challenging market environment for the coal industry as the U.S. experienced significant year-over-year declines in coal-fired electricity generation causing a steep reduction in domestic coal demand. Recently, hotter weather patterns, rising natural gas prices, strong export thermal sales and supply reductions by other coal producers gives us hope that better days are ahead for the coal markets. We still are concerned, however, about a weak U.S. economy and the direction of the global economy. This weakness and uncertainty has impacted demand and pricing for our metallurgical coal sales for the remainder of this year. We expect to ship the last 70,000 tons on our high-priced export contract in July. We are in negotiations to continue shipping into the export metallurgical market but cannot predict if, or when, shipments will resume. On a positive note, at Tunnel Ridge our production was 300,000 tons in the 2012 Quarter and is expected to grow to 900,000 tons in the third quarter of 2012 and reach 1.2 million tons in the fourth quarter of this year. With our strong balance sheet and contract portfolio, as well as the increased production from Tunnel Ridge, ARLP is well positioned to manage through these near-term challenges and we expect to deliver record EBITDA results consistent with previous guidance."
Reflecting results to date and adjusting for current coal sales and production mix expectations, ARLP currently anticipates full-year 2012 results near the lower end of its previous guidance ranges for production volumes of 35.2 to 36.4 million tons, sales volumes of 35.6 to 36.9 million tons and revenues, excluding transportation revenues, of $2.06 to $2.12 billion.
Based on current expectations, ARLP is essentially fully priced and committed for its anticipated 2012 coal sales volumes. ARLP has also secured coal sales commitments for approximately 36.1 million tons, 29.3 million tons and 22.8 million tons in 2013, 2014 and 2015, respectively, of which approximately 1.0 million tons in 2013 and 2.9 million tons in both 2014 and 2015 remain open to market pricing.
For 2012, ARLP is anticipating full-year results near the midpoint of its previous guidance ranges for consolidated EBITDA of $585.0 to $615.0 million and net income of $345.0 to $385.0 million. Consolidated estimates for 2012 continue to reflect the negative effects of ARLPs White Oak investments, which are now estimated in a range of $15.0 to $20.0 million for EBITDA and $12.0 to $17.0 million for net income. (For a definition of EBITDA and related reconciliations to comparable GAAP financial measures, please see the end of this release.)
ARLP continues to anticipate total 2012 capital expenditures in a range of $565.0 to $610.0 million, including approximately $95.0 to $110.0 million for reserve acquisitions and construction of surface facilities related to the White Oak mine development project. In addition, ARLP now expects to fund approximately $75.0 to $95.0 million of its preferred equity investment commitment to White Oak during 2012.
A conference call regarding ARLPs 2012 Quarter financial results is scheduled for today at 10:00 a.m. Eastern. To participate in the conference call, dial (866) 510-0704 and provide pass code 87258002. International callers should dial (617) 597-5362 and provide the same pass code. Investors may also listen to the call via the "investor information" section of ARLPs 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 (888) 286-8010 and provide pass code 62224575. International callers should dial (617) 801-6888 and provide the same pass code.
This announcement is intended to be a qualified notice under Treasury Regulation Section 1.1446-4(b), with 100% of the partnerships distributions to foreign investors attributable to income that is effectively connected with a United States trade or business. Accordingly, ARLPs 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, Northern Appalachian and Central Appalachian coal producing regions. ARLP operates eleven mining complexes in Illinois, Indiana, Kentucky, Maryland and West Virginia. ARLP is also constructing a new mine in southern Indiana and is purchasing and funding development of reserves, constructing surface facilities and making equity investments in a new mining complex in southern Illinois. 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 ARLP at (918) 295-7674 or via e-mail at firstname.lastname@example.org.
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. These projections do not include the potential impact of any mergers, acquisitions or other business combinations that may occur after the date of this release. 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; the impact of health care legislation; 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 due to labor and transportation costs and disruptions, equipment availability, governmental regulations, including those related to carbon dioxide emissions, and other factors; legislation, regulatory and court decisions and interpretations thereof, including issues related to air and water quality and miner health and safety; our productivity levels and margins earned on our coal sales; unexpected changes in raw material costs; unexpected changes in the availability of skilled labor; our ability to maintain satisfactory relations with our employees; any unanticipated increases in labor costs, adverse changes in work rules, or unexpected cash payments or projections associated with post-mine reclamation and workers2 compensation claims; any unanticipated increases in transportation costs and risk of transportation delays or interruptions; greater than expected environmental regulation, costs and liabilities; a variety of operational, geologic, permitting, labor and weather-related 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 workers2 compensation and black lung benefits; difficulty in making accurate assumptions and projections regarding pension, black lung benefits and other post-retirement benefit liabilities; coal market'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 alternative sources of energy, 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 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 ARLPs public periodic filings with the Securities and Exchange Commission ("SEC"), including ARLPs Annual Report on Form 10-K for the year ended December 31, 2011, filed on February 28, 2012 with the SEC. Except as required by applicable securities laws, ARLP does not intend to update its forward-looking statements.
|ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES|
|CONDENSED CONSOLIDATED STATEMENTS OF INCOME AND OPERATING DATA|
|(In thousands, except unit and per unit data)|
|Three Months Ended||Six Months Ended|
|June 30,||June 30,|
|SALES AND OPERATING REVENUES:|
|Other sales and operating revenues||11,918||6,757||19,320||13,030|
|Operating expenses (excluding depreciation, depletion and amortization)||334,647||284,117||608,162||540,235|
|Outside coal purchases||16,154||5,842||30,335||9,631|
|General and administrative||16,052||13,002||30,341||25,422|
|Depreciation, depletion and amortization||52,109||39,100||95,142||76,962|
|Total operating expenses||424,403||350,767||776,006||670,256|
|INCOME FROM OPERATIONS||105,461||107,179||197,444||210,948|
|Interest expense, net||(8,268||)||(9,156||)||(14,180||)||(18,466||)|
|Equity in loss of affiliates, net||(4,430||)||-||(8,208||)||-|
|INCOME BEFORE INCOME TAXES||95,198||98,503||177,799||193,654|
|INCOME TAX EXPENSE (BENEFIT)||(257||)||325||(624||)||96|
|GENERAL PARTNERS INTEREST IN NET INCOME||$||27,165||$||22,209||$||52,752||$||43,214|
|LIMITED PARTNERS INTEREST IN NET INCOME||$||68,290||$||75,969||$||125,671||$||150,344|
|BASIC AND DILUTED NET INCOME PER LIMITED PARTNER UNIT||$||1.83||$||2.04||$||3.36||$||4.03|
|DISTRIBUTIONS PAID PER LIMITED PARTNER UNIT||$||1.025||$||0.89||$||2.015||$||1.75|
|WEIGHTED AVERAGE NUMBER OF UNITS OUTSTANDING BASIC AND DILUTED||36,874,949||36,775,741||36,850,965||36,762,402|
|ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES|
|CONDENSED CONSOLIDATED BALANCE SHEETS|
|(In thousands, except unit data)|
|June 30,||December 31,|
|Cash and cash equivalents||$||11,364||$||273,528|
|Due from affiliates||255||5,116|
|Prepaid expenses and other assets||6,493||11,945|
|Total current assets||260,030||464,154|
|PROPERTY, PLANT AND EQUIPMENT:|
|Property, plant and equipment, at cost||2,274,804||1,974,520|
|Less accumulated depreciation, depletion and amortization||(797,909||)||(793,200||)|
|Total property, plant and equipment, net||1,476,895||1,181,320|
|Equity investments in affiliates||63,880||40,118|
|Other long-term assets||27,200||18,010|
|Total other assets||121,928||86,044|
|LIABILITIES AND PARTNERS' CAPITAL|
|Due to affiliates||567||494|
|Accrued taxes other than income taxes||21,219||15,873|
|Accrued payroll and related expenses||37,049||35,876|
|Workers compensation and pneumoconiosis benefits||9,466||9,511|
|Current capital lease obligations||1,037||676|
|Other current liabilities||22,352||15,326|
|Current maturities, long-term debt||18,000||18,000|
|Total current liabilities||228,414||194,820|
|Long-term debt, excluding current maturities||691,000||686,000|
|Accrued pension benefit||24,723||27,538|
|Asset retirement obligations||76,220||70,836|
|Long-term capital lease obligations||19,115||2,497|
|Total long-term liabilities||951,075||912,940|
|COMMITMENTS AND CONTINGENCIES|
|Alliance Resource Partners, L.P. Partners Capital:|
|Limited Partners - Common Unitholders 36,874,949 and 36,775,741 units outstanding, respectively||993,747||943,325|
|General Partners' deficit||(275,226||)||(279,107||)|
|Accumulated other comprehensive loss||(39,157||)||(40,460||)|
|Total Partners' Capital||679,364||623,758|
|TOTAL LIABILITIES AND PARTNERS' CAPITAL||$||1,858,853||$||1,731,518|
|ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES|
|CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS|
|Six Months Ended|
|CASH FLOWS PROVIDED BY OPERATING ACTIVITIES||$||255,471||$||261,385|
|CASH FLOWS FROM INVESTING ACTIVITIES:|
|Property, plant and equipment:|
|Changes in accounts payable and accrued liabilities||10,759||(5,524||)|
|Proceeds from sale of property, plant and equipment||19||122|
|Purchase of equity investments in affiliate||(30,600||)||-|
|Payment for acquisition of business||(100,000||)||-|
|Payments to affiliate for development of coal reserves||(34,601||)||-|
|Advances/loans to affiliate||(2,229||)||-|
|Payments from affiliate||4,229||-|
|Net cash used in investing activities||(390,324||)||(147,025||)|
|CASH FLOWS FROM FINANCING ACTIVITIES:|
|Borrowings under term loan||250,000||-|
|Borrowings under revolving credit facility||55,000||-|
|Payment on term loan||(300,000||)||-|
|Payments on capital lease obligations||(405||)||(379||)|
|Payment of debt issuance costs||(4,272||)||-|
Net settlement of employee withholding taxes on vesting of Long-Term Incentive Plan
|Cash contributions by General Partners||150||87|
|Distributions paid to Partners||(124,050||)||(104,195||)|
|Net cash used in financing activities||(127,311||)||(106,811||)|
|NET CHANGE IN CASH AND CASH EQUIVALENTS||(262,164||)||7,549|
|CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD||273,528||339,562|
|CASH AND CASH EQUIVALENTS AT END OF PERIOD||$||11,364||$||347,111|
Reconciliation of GAAP "Net Income" to non-GAAP "EBITDA" and non-GAAP "Distributable Cash Flow" (in thousands).
EBITDA is defined as net income 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 interest expense (before capitalized interest), interest income, income taxes and estimated maintenance capital expenditures. DCF 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 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 through the investment community with respect to publicly-traded partnerships as the value of a unit is generally determined by a units 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 and DCF may not be the same method used to compute similar measures reported by other companies, and EBITDA and DCF may be computed differently by us in different contexts (i.e. public reporting versus computation under financing agreements).
|Three Months Ended||Six Months Ended||Ended||Year Ended|
|June 30,||June 30,||March 31,||December 31,|
|Depreciation, depletion and amortization||52,109||39,100||95,142||76,962||43,033||209,000|
|Interest expense, gross||9,995||9,236||18,768||18,586||8,773||37,000|
|Income tax expense (benefit)||(257||)||325||(624||)||96||(367||)||(1,500||)|
|Interest expense, gross||(9,995||)||(9,236||)||(18,768||)||(18,586||)||(8,773||)||(37,000||)|
|Income tax (expense) benefit||257||(325||)||624||(96||)||367||1,500|
|Estimated maintenance capital expenditures (1)||(45,018||)||(35,415||)||(91,834||)||(74,049||)||(46,816||)||(195,800||)|
|Distributable Cash Flow||$||100,768||$||101,696||$||176,999||$||196,159||$||76,231||$||368,700|
(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 current five-year planning horizon, average annual estimated maintenance capital expenditures are assumed to be $5.50 per produced ton compared to the estimated $4.70 per produced ton in 2011. Our actual maintenance capital expenditures vary depending on various factors, including maintenance schedules and timing of capital projects, among others. We annually disclose our actual maintenance capital expenditures in our Form 10-K filed with the Securities and Exchange Commission.
Reconciliation of GAAP "Operating Expenses" to non-GAAP "Segment Adjusted EBITDA Expense per ton" and Reconciliation of non-GAAP "EBITDA" to "Segment Adjusted EBITDA" (in thousands, except per ton data).
Segment Adjusted EBITDA Expense per ton includes operating expenses, outside coal purchases and other income divided by tons sold. Transportation expenses are excluded as these expenses are passed through to our customers and, consequently, we do not realize any margin on transportation revenues. Segment Adjusted EBITDA Expense is used as a supplemental financial measure by our management to assess the operating performance of our segments. Segment Adjusted EBITDA Expense is a key component of EBITDA in addition to coal sales and other sales and operating revenues. The exclusion of corporate general and administrative expenses from Segment Adjusted EBITDA Expense allows management to focus solely on the evaluation of segment operating performance as it primarily relates to our operating expenses. Outside coal purchases are included in Segment Adjusted EBITDA Expense because tons sold and coal sales include sales from outside coal purchases.
Three Months Ended
|Outside coal purchases||16,154||5,842||14,181|
|Other (income) loss||(2,384||)||(393||)||(215||)|
|Segment Adjusted EBITDA Expense||$||348,417||$||289,566||$||287,481|
|Divided by tons sold||8,661||7,890||7,812|
|Segment Adjusted EBITDA Expense per ton||$||40.23||$||36.70||$||36.80|
Segment Adjusted EBITDA is defined as net income before net interest expense, income taxes, depreciation, depletion and amortization and general and administrative expenses.
Three Months Ended
|EBITDA (See reconciliation to GAAP above)||$||155,524||$||146,672||$||131,453|
|General and administrative||16,052||13,002||14,289|
|Segment Adjusted EBITDA||$||171,576||$||159,674||$||145,742|
Alliance Resource Partners, L.P.
Brian L. Cantrell, 918-295-7673
Source: Alliance Resource Partners, L.P.Copyright Business Wire 2012