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Alliance Resource Partners, L.P. Reports Record Annual Financial and Operating Results

Posted on: Monday, 29 January 2007, 09:00 CST

Alliance Resource Partners, L.P. (NASDAQ: ARLP) today reported record annual financial results for the year ended December 31, 2006 ("2006 Period"). ARLP's net income for the 2006 Period increased 8.1% to a record $172.9 million, or $4.03 of adjusted net income per diluted limited partner unit, compared to net income of $160.0 million, or $3.99 of adjusted net income per diluted limited partner unit, for the year ended December 31, 2005 ("2005 Period"). ARLP's use of adjusted net income per limited partner unit is consistent with methodology generally used by securities analysts and consensus estimates. ARLP also reported record 2006 Period EBITDA of $250.8 million, an increase of 9.0% over EBITDA of $230.1 million in the 2005 Period. (For definitions of adjusted net income per limited partner unit and EBITDA and related reconciliations to GAAP, please see the end of this release.)

ARLP also announced the Board of Directors of its managing general partner (the "Board") declared a quarterly cash distribution for the fourth quarter of 2006 of $0.54 per unit, an annualized rate of $2.16 per unit, payable on February 14, 2007 to all unitholders of record as of February 7, 2007. This distribution represents an increase of 8.0% over the third quarter 2006 cash distribution of $0.50 per unit, an annualized rate of $2.00 per unit. Increases to ARLP's quarterly cash distribution to unitholders are generally considered by the Board at its January and July meetings.

"For the sixth year in a row, ARLP delivered record financial and operating performances, setting new standards for coal sales, production volumes, revenues, EBITDA and net income," said Joseph W. Craft III, President and Chief Executive Officer. "I am pleased that our strong performance allowed ARLP to increase cash distributions to our unitholders by more than 17.4% over the past twelve months while maintaining one of the highest distribution coverage ratios in the MLP sector."

For the quarter ended December 31, 2006 ("2006 Quarter"), ARLP reported net income of $45.5 million, or $1.03 of adjusted net income per diluted limited partner unit, compared to net income of $45.7 million, or $1.11 of adjusted net income per diluted limited partner unit, for the quarter ended December 31, 2005 ("2005 Quarter"). EBITDA in the 2006 Quarter increased to a record $66.7 million, compared to EBITDA of $63.0 million in the 2005 Quarter. (For definitions of adjusted net income per limited partner unit and EBITDA and related reconciliations to GAAP, please see the end of this release.)

Consolidated Financial Results

Revenues in the 2006 Quarter increased 15.8% to a record $263.2 million, compared to revenues of $227.3 million in the 2005 Quarter. Increased revenues were primarily attributable to record levels for both coal sales volumes and average coal sales prices per ton during the 2006 Quarter. ARLP's total coal sales volumes increased to a record 6.5 million tons of coal sold during the 2006 Quarter, compared to 5.9 million tons sold during the 2005 Quarter. Average coal sales prices realized by ARLP during the 2006 Quarter increased $1.86 per ton to a record $37.34 per ton. Higher synfuel-related revenues, which increased $2.6 million to $7.6 million during the 2006 Quarter, also contributed to increased revenues.

Increased coal sales volumes as well as industry-wide cost pressures and ongoing costs associated with transitions into three of our newer mining operations led to higher operating expenses during the 2006 Quarter of $172.7 million, compared to $144.1 million for the 2005 Quarter. Also, during the 2006 Quarter, ARLP continued to experience increases in labor related expenses, materials and supply costs (particularly consumables such as steel and power) and maintenance expense. Operating expenses during the 2006 Quarter were also impacted by ARLP's response to increasing federal and state mine safety laws and regulations imposed on the U.S. coal mining industry. Higher coal sales volumes and revenues during the 2006 Quarter likewise resulted in higher sales related expenses.

General and administrative expenses increased during the 2006 Quarter to $9.2 million from $4.4 million during the 2005 Quarter, primarily as a result of higher unit-based incentive compensation expense in the 2006 Quarter. Increased capital spending related to ARLP's growth initiatives resulted in higher depreciation, depletion and amortization expense, which rose $3.4 million during the 2006 Quarter to $18.2 million.

For the full year 2006, ARLP reported record revenues of $967.6 million, on the strength of record levels for both coal sales volumes and average coal sales prices per ton. This represents a 15.4% increase over 2005 Period revenues of $838.7 million. Coal sales volumes increased in each of ARLP's operating regions, growing to a record 24.4 million tons sold during the 2006 Period from 22.8 million tons during the 2005 Period. ARLP also realized higher coal sales prices per ton during the 2006 Period, increasing 9.3% to a record $36.79 per ton. Total coal production also climbed to a record 23.7 million tons during the 2006 Period, an increase of 6.5% over the 22.3 million tons of coal produced during the 2005 Period.

Operating expenses for the full year 2006 increased to $627.8 million, compared to $521.5 million during the 2005 Period, primarily as a result of the same factors discussed above which impacted operating expenses in the 2006 Quarter. Also contributing to increased operating expenses in the 2006 Period were higher outside coal purchases, which increased to $19.2 million in the 2006 Period compared to $15.1 million in the 2005 Period, as ARLP responded to several attractive market opportunities throughout the year. General and administrative expenses decreased $2.6 million to $30.9 million during the 2006 Period, primarily as a result of lower unit-based incentive compensation. Increased capital spending throughout 2006 led to higher depreciation, depletion and amortization expense, which rose $10.9 million to $66.5 million.

Regional Results and Analysis

Illinois Basin

Central Appalachia

Northern Appalachia

Total (4)

2006 Qtr

2005 Qtr

2006 Qtr

2005 Qtr

2006 Qtr

2005 Qtr

2006 Qtr

2005 Qtr

Tons sold (millions)

4.711 

4.091 

0.878 

0.904 

0.922 

0.871 

6.514 

5.873 

Coal sales price per ton (1)

$34.25 

$31.81 

$52.34 

$50.25 

$33.69 

$33.69 

$37.34 

$35.48 

Adjusted EBITDA expense per ton (2)

$23.21 

$22.34 

$41.84 

$36.68 

$27.95 

$23.91 

$27.23 

$25.19 

Adjusted EBITDA (millions) (3)

$59.6 

$44.1 

$9.3 

$12.4 

$5.7 

$9.0 

$75.9 

$67.5 

(1) Sales price per ton is defined as total coal sales divided by total tons sold.

(2) Adjusted EBITDA expense per ton represents the sum of operating expenses, outside purchases and other income divided by total tons sold.

(3) For a definition of Adjusted EBITDA and reconciliation to GAAP, please see the end of this release.

(4) Total includes other and corporate.

ARLP's coal sales volumes for the 2006 Quarter increased approximately 643,000 tons, or 10.9% over the 5.9 million tons of coal sold in the 2005 Quarter, primarily as a result of higher sales volumes at its Illinois Basin operations. Coal sales volumes in the Illinois Basin region increased 15.2% primarily due to increased productivity at the Elk Creek, Warrior and Gibson County mines and a continued reduction of coal inventory accumulated during construction of the new preparation plant at Elk Creek. In the Northern Appalachia region, coal production declined during the 2006 Quarter as ARLP completed the transition of longwall operations from the Mettiki mine, in Maryland, to the Mountain View mine, in West Virginia. Despite reduced coal production during this transition, coal sales volumes in the 2006 Quarter increased 5.9% over the 2005 Quarter sales volumes primarily as a result of ARLP's planned reduction of inventory accumulated at the Mettiki mine to meet sales commitments to Northern Appalachian customers during the longwall transition.

Total average coal sales prices per ton for the 2006 Quarter increased 5.2% over the 2005 Quarter to a record $37.34 per ton sold. Reflecting the impact of new coal sales agreements and the re-pricing of several long-term coal sales contracts at higher prices, average coal sales prices in the Illinois Basin region increased 7.7% in the 2006 Quarter, compared to the 2005 Quarter. Improved contract pricing in the Central Appalachian region also resulted in higher sales prices per ton as average coal sales prices increased 4.2% during the 2006 Quarter.

Total Adjusted EBITDA expense per ton increased 8.1% during the 2006 Quarter to $27.23 per ton sold, primarily due to the impact of the previously discussed higher costs and expenses in each of the ARLP's operating regions. Adjusted EBITDA expenses in the Illinois Basin region were also impacted by costs related to adverse mining conditions experienced during the 2006 Quarter at the Pattiki mine. Higher costs at the Pontiki mine associated with ramping to full production in the Van Lear seam and transitioning to the Albridge Branch area of the Pond Creek seam also contributed to increased Adjusted EBITDA expense per ton in the Central Appalachian region during the 2006 Quarter. Increased Adjusted EBITDA expense per ton in the Northern Appalachian region also reflects the previously discussed transition of longwall operations during the 2006 Quarter. In addition, primarily due to higher West Virginia severance taxes and the loss of certain Maryland state tax benefits, the transition of mining operations from Mettiki to Mountain View further increased Adjusted EBITDA expense per ton. Although higher taxes associated with the Mountain View mining operation will increase future Adjusted EBITDA expenses in the Northern Appalachian region, revenues from new coal sales contracts are expected to offset these higher costs. (For a definition of Adjusted EBITDA and reconciliation to GAAP, please see the end of this release.)

Outlook

"Mild weather patterns, higher utility stockpiles and increased coal production have all contributed to a significant softening in recent spot market prices for domestic coal," said Mr. Craft. "While this weaker pricing environment is likely to persist over the near term, we remain confident that the long term supply/demand fundamentals for coal are positive, particularly in the Illinois Basin and Northern Appalachia as demand for scrubber quality coal continues to increase in those markets. We continue to believe in our strategy of positioning ARLP to benefit from the anticipated demand growth in these scrubber markets. Consequently, although the short term factors currently impacting the coal markets may influence our timing, we continue to focus our efforts on securing the mine permits and long term coal sales commitments needed to bring our growth projects at River View, Gibson South, Tunnel Ridge and Penn Ridge into production."

ARLP's capital expenditures for 2006 totaled $188.6 million. These investments included the development of the Elk Creek and Mountain View mines, the transition of the Pontiki mine into the Van Lear seam and the Albridge Branch area of the Pond Creek seam, commencement of construction of the rail load out facility at the Gibson County mine and initial development costs associated with the ARLP's other growth projects. The balance of 2006 capital expenditures related primarily to infrastructure improvements and efficiency projects at the Gibson County, MC Mining and Mt. Vernon transfer terminal operations, and maintenance capital expenditures.

Total capital expenditures for 2007 are currently estimated in a range of $100.0 to $115.0 million. These estimated capital expenditures include investments for completion of the rail load out facility at the Gibson County mine, compliance associated with increased federal and state mine safety laws and regulations, new infrastructure and efficiency projects at various operations and development costs associated with previously announced growth projects. Sustainable maintenance capital expenditures are expected to be approximately $2.75 per ton produced. Additionally, ARLP expects depreciation expense to increase to approximately $86.8 million in 2007 as compared to $66.5 million in 2006.

ARLP is currently anticipating coal production for 2007 will increase approximately 6.0% over 2006 production levels to a range of 24.7 to 25.2 million tons. Despite the current weakness in spot market prices for coal, ARLP currently expects its average coal sales price per ton to increase modestly in 2007, by approximately 4.0% - 5.0% over its 2006 average coal sales price per ton, due to recent re-pricing of several lower priced long-term coal sales contracts at higher market prices. Based on these anticipated increases in coal production and coal sales prices, ARLP is currently estimating 2007 revenues will increase approximately 8.0% over 2006 revenues to a range of $985.0 to $1,015.0 million, excluding transportation revenues. Total coal sales volumes open to market pricing includes approximately 3.2 million tons in 2007, 13.1 million tons in 2008 and 20.8 million tons in 2009.

Costs attributable to labor and benefits, maintenance, regulatory requirements and materials and supplies are expected to remain under pressure in 2007. As a result of these anticipated cost increases and higher costs attributable to increased production, sales related expenses and mine development costs, ARLP is currently estimating 2007 operating expenses will increase approximately 11.0% over 2006 levels. Based on its current projections for 2007, ARLP is estimating EBITDA in a range of $255.0 to $285.0 million and net income in a range of $155.0 to $185.0 million. Guidance ranges for EBITDA and net income exclude the impact of any additional expenses, losses, or insurance recoveries attributable to the Excel No. 3 mine fire, which occurred in December, 2004. (For a definition of EBITDA and reconciliation to GAAP, please see the end of this release.)

Guidance ranges for 2007 revenues, EBITDA, and net income include an estimated benefit in a range of approximately $25.0 to $27.0 million from ARLP's various coal synfuel-related agreements. Realization of future synfuel related benefits could be reduced if non-conventional synfuel tax credits become unavailable to the owners of the coal synfuel facilities due to a rise in the price of crude oil or otherwise. The non-conventional synfuel tax credit is scheduled to expire on December 31, 2007.

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.

ARLP is a diversified producer and marketer of steam coal to major United States utilities and industrial users. ARLP, the nation's only publicly traded master limited partnership involved in the production and marketing of coal, is currently the fifth largest coal producer in the eastern United States with operations in all major eastern coalfields. ARLP currently operates eight underground mining complexes in Illinois, Indiana, Kentucky, Maryland and West Virginia.

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 investorrelations@arlp.com.

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: increased competition in coal markets and our ability to respond to the competition; fluctuation in coal prices, which could adversely affect our operating results and cash flows; risks associated with the expansion of our operations and properties; deregulation of the electric utility industry or the effects of any adverse change in the domestic coal industry, electric utility industry, or general economic conditions; dependence on significant customer contracts, including renewing customer contracts upon expiration of existing contracts; customer bankruptcies and/or cancellations or breaches of existing contracts; customer delays or defaults in making payments; fluctuations in coal demand, prices and availability due to labor and transportation costs and disruptions, equipment availability, governmental regulations and other factors; our productivity levels and margins that we earn on our coal sales; greater than expected increases in raw material costs; greater than expected shortage of skilled labor; any unanticipated increases in labor costs, adverse changes in work rules, or unexpected cash payments associated with post-mine reclamation and workers' 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; risk associated with major mine-related accidents, such as mine fires or other interruptions; results of litigation; difficulty maintaining our surety bonds for mine reclamation as well as workers' compensation and black lung benefits; difficulty obtaining commercial property insurance, and risks associated with our increased participation (excluding any applicable deductible) in the commercial insurance property program; and, a loss or reduction of the direct or indirect benefit from certain state and federal tax credits, including non-conventional source fuel tax credits.

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, 2005, filed on March 16, 2006 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)

(Unaudited)

Three Months Ended

December 31,

Year-Ended

December 31,

2006 

2005 

2006 

2005 

Tons sold

6,515 

5,872 

24,351 

22,849 

Tons produced

5,574 

5,568 

23,738 

22,290 

SALES AND OPERATING REVENUES:

Coal sales

$ 243,296 

$ 208,346 

$ 895,823 

$ 768,958 

Transportation revenues

9,923 

11,962 

39,879 

39,069 

Other sales and operating revenues

9,974 

7,024 

31,855 

30,691 

Total revenues

263,193 

227,332 

967,557 

838,718 

EXPENSES:

Operating expenses

172,660 

144,058 

627,756 

521,488 

Transportation expenses

9,923 

11,962 

39,879 

39,069 

Outside purchases

4,962 

4,132 

19,213 

15,113 

General and administrative

9,244 

4,417 

30,884 

33,484 

Depreciation, depletion and amortization

18,206 

14,815 

66,489 

55,637 

Total operating expenses

214,995 

179,384 

784,221 

664,791 

INCOME FROM OPERATIONS

48,198 

47,948 

183,336 

173,927 

Interest expense

(2,719)

(3,008)

(12,177)

(14,617)

Interest income

477 

877 

3,002 

2,801 

Other income

252 

267 

936 

581 

INCOME BEFORE INCOME TAXES, CUMULATIVE EFFECT OF ACCOUNTING CHANGE AND MINORITY INTEREST

46,208 

46,084 

175,097 

162,692 

INCOME TAX EXPENSE

785 

426 

2,443 

2,682 

INCOME BEFORE CUMULATIVE EFFECT OF ACCOUNTING CHANGE AND MINORITY INTEREST

45,423 

45,658 

172,654 

160,010 

CUMULATIVE EFFECT OF ACCOUNTING CHANGE

- 

- 

112 

- 

MINORITY INTEREST

65 

- 

161 

- 

NET INCOME

$ 45,488 

$ 45,658 

$ 172,927 

$ 160,010 

GENERAL PARTNERS' INTEREST IN NET INCOME

$ 7,609 

$ 4,792 

$ 24,594 

$ 12,409 

LIMITED PARTNERS' INTEREST IN NET INCOME

$ 37,879 

$ 40,866 

$ 148,333 

$ 147,601 

BASIC NET INCOME PER LIMITED PARTNER UNIT

$ 0.80 

$ 0.80 

$ 3.06 

$ 2.89 

DILUTED NET INCOME PER LIMITED PARTNER UNIT

$ 0.79 

$ 0.79 

$ 3.03 

$ 2.84 

DISTRIBUTIONS PAID PER COMMON UNIT

$ 0.50 

$ 0.41 

$ 1.92 

$ 1.58 

WEIGHTED AVERAGE NUMBER OF UNITS

OUTSTANDING-BASIC

36,422,515 

36,370,565 

36,425,350 

36,288,527 

WEIGHTED AVERAGE NUMBER OF UNITS

OUTSTANDING-DILUTED

36,852,765 

36,923,444 

36,810,383 

36,977,061 

ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(In thousands, except unit data)

(Unaudited)

December 31,

2006 

2005 

ASSETS

CURRENT ASSETS:

Cash and cash equivalents

$ 36,789 

$ 32,054 

Trade receivables, net

96,558 

94,495 

Other receivables

3,378 

2,330 

Due from affiliates

25 

- 

Marketable securities

260 

49,242 

Inventories

20,224 

17,270 

Advance royalties

4,629 

2,952 

Prepaid expenses and other assets

8,225 

8,934 

Total current assets

170,088 

207,277 

PROPERTY, PLANT AND EQUIPMENT:

Property, plant and equipment at cost

819,991 

635,086 

Less accumulated depreciation, depletion and amortization

(383,284)

(330,672)

Total property, plant and equipment

436,707 

304,414 

OTHER ASSETS:

Advance royalties

22,135 

16,328 

Other long-term assets

6,032 

4,668 

Total other assets

28,167 

20,996 

TOTAL ASSETS

$ 634,962 

$ 532,687 

LIABILITIES AND PARTNERS' CAPITAL

CURRENT LIABILITIES:

Accounts payable

$ 57,879 

$ 53,473 

Due to affiliates

1,414 

8,795 

Accrued taxes other than income taxes

14,618 

13,177 

Accrued payroll and related expenses

14,698 

12,466 

Accrued pension benefit

- 

7,588 

Accrued interest

4,264 

4,855 

Workers' compensation and pneumoconiosis benefits

7,704 

7,740 

Current capital lease obligation

339 

- 

Other current liabilities

13,786 

5,120 

Current maturities, long-term debt

18,000 

18,000 

Total current liabilities

132,702 

131,214 

LONG-TERM LIABILITIES:

Long-term debt, excluding current maturities

126,000 

144,000 

Pneumoconiosis benefits

26,315 

23,293 

Accrued pension benefit

6,191 

- 

Workers' compensation

38,488 

30,050 

Reclamation and mine closing

47,825 

38,716 

Due to affiliates

994 

6,940 

Long-term capital lease obligation

1,512 

- 

Minority interest

839 

- 

Other liabilities

5,616 

2,697 

Total long-term liabilities

253,780 

245,696 

Total liabilities

386,482 

376,910 

COMMITMENTS AND CONTINGENCIES

PARTNERS' CAPITAL:

Limited Partners -- Common Unitholders 36,419,847 and 36,426,306 units outstanding, respectively

549,005 

461,068 

General Partners' deficit

(293,569)

(298,270)

Unrealized loss on marketable securities

- 

(68)

Minimum pension liability

(6,956)

(6,953)

Total Partners' capital

248,480 

155,777 

TOTAL LIABILITIES AND PARTNERS' CAPITAL

$ 634,962 

$ 532,687 

ALLIANCE RESOURCE PARTNERS, L.P. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(In thousands)

(Unaudited)

Year Ended

December 31,

2006 

2005 

CASH FLOWS PROVIDED BY OPERATING ACTIVITIES

$ 250,923 

$ 193,618 

CASH FLOWS FROM INVESTING ACTIVITIES:

Property, plant and equipment:

Capital expenditures

(188,630)

(116,094)

Changes in accounts payable and accrued liabilities

2,776 

5,577 

Proceeds from sale of property, plant and equipment

1,401 

198 

Purchase of marketable securities

(19,447)

(63,448)

Proceeds from marketable securities

68,497 

63,589 

Payments for acquisition of business

(2,289)

- 

Net cash used in investing activities

(137,692)

(110,178)

CASH FLOWS FROM FINANCING ACTIVITIES:

Payments on long-term debt

(18,000)

(18,000)

Cash contribution by General Partners

2 

143 

Payment of debt issuance cost

(690)

- 

Equity contribution received by Mid-America Carbonates, LLC

1,000 

- 

Distributions to Partners

(90,808)

(64,706)

Net cash used in financing activities

(108,496)

(82,563)

NET CHANGE IN CASH AND CASH EQUIVALENTS

4,735 

877 

CASH AND CASH EQUIVALENTS AT BEGINNING OF PERIOD

32,054 

31,177 

CASH AND CASH EQUIVALENTS AT END OF PERIOD

$ 36,789 

$ 32,054 

CASH PAID FOR:

Interest

$ 13,760 

$ 15,160 

Income taxes to taxing authorities

$ 2,400 

$ 3,025 

NON-CASH INVESTING ACTIVITY

Purchase of property, plant and equipment

$ 12,139 

$ 9,364 

Asset acquired by capital lease

$ 1,862 

$ - 

Market value of common units issued to long-term incentive plan participants upon vesting

$ - 

$ 6,988 

Reconciliation of GAAP "Cash Flows Provided by Operating Activities" to Non-GAAP "EBITDA", Reconciliation of non-GAAP "EBITDA" to GAAP "Net Income" and Reconciliation of non-GAAP EBITDA to Adjusted EBITDA (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.

EBITDA should not be considered as an alternative 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 is not intended to represent cash flow and does not represent the measure of cash available for distribution. Our method of computing EBITDA may not be the same method used to compute similar measures reported by other companies, or EBITDA may be computed differently by us in different contexts (i.e. public reporting versus computation under financing agreements).

Adjusted EBITDA is defined as net income before income tax expense (benefit), net interest expense, depreciation, depletion and amortization, and general and administrative expenses.

Three Months Ended

December 31,

Year Ended

December 31,

Year Ended

December 31,

2006 

2005 

2006 

2005 

2007E

Midpoint

Cash flows provided by operating activities

$ 66,473 

$ 42,049 

$ 250,923 

$ 193,618 

$ 253,400 

Long-term incentive plan

(1,020)

1,372 

(4,112)

(8,193)

(3,100)

Reclamation and mine closing

(538)

(568)

(2,101)

(1,918)

(2,200)

Coal inventory adjustment to market

1,321 

(506)

(319)

(573)

- 

Net gain (loss) on sale of property, plant and equipment

747 

(2)

1,188 

(179)

- 

Loss on retirement of damaged vertical belt equipment

- 

- 

- 

(1,298)

- 

Other

(628)

(142)

(1,119)

(580)

(300)

Net effect of working capital changes

(2,726)

18,270 

(5,317)

34,770 

9,200 

Interest expense, net

2,242 

2,131 

9,175 

11,816 

10,200 

Income taxes

785 

426 

2,443 

2,682 

2,800 

EBITDA

66,656 

63,030 

250,761 

230,145 

270,000 

Depreciation, depletion and amortization

(18,206)

(14,815)

(66,489)

(55,637)

(86,800)

Interest expense, net

(2,242)

(2,131)

(9,175)

(11,816)

(10,200)

Income taxes

(785)

(426)

(2,443)

(2,682)

(2,800)

Cumulative effect of accounting change

- 

- 

112 

- 

- 

Minority interest income

65 

- 

161 

- 

(200)

Net income

$ 45,488 

$ 45,658 

$ 172,927 

$ 160,010 

$ 170,000 

Three Months Ended

December 31,

2006 

2005 

EBITDA

$ 66,656 

$ 63,030 

General and administrative

9,244 

4,417 

Adjusted EBITDA

$ 75,900 

$ 67,447 

Reconciliation of GAAP "Net Income per Limited Partner Unit" reflecting the impact of EITF 03-6 to non-GAAP "Adjusted Net Income per Limited Partner Unit"

Net income per limited partner unit as dictated by EITF 03-6 is theoretical and pro forma in nature and does not reflect the economic probabilities of whether earnings for an accounting period would or could be distributed to unitholders. The Partnership Agreement does not provide for the distribution of net income, rather, it provides for the distribution of available cash, which is a contractually defined term that generally means all cash on hand at the end of each quarter after establishment of sufficient cash reserves required to operate the ARLP in a prudent manner. Accordingly, the distributions we have paid historically and will pay in future periods are not impacted by net income per limited partner unit as dictated by EITF 03-6.

In addition to net income per limited partner unit as calculated in accordance with EITF 03-6, we intend to continue to present "adjusted net income per limited partner unit," as reflected in the table above, which is consistent with our presentation of net income per limited partner unit in prior periods. "Adjusted net income per limited partner unit," as presented in the table above, is defined as net income after deducting the amount allocated to the general partners' interests, including the managing general partner's incentive distribution rights, divided by the weighted average number of outstanding limited partner units during the period. As part of this calculation, in accordance with the cash distribution requirements contained in the Partnership Agreement, net income is first allocated to the managing general partner based on the amount of incentive distributions attributable to the period. The remainder is then allocated between the limited partners and the general partners based on their respective percentage ownership in ARLP. Adjusted net income per limited partner unit 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 actual operation of our Partnership Agreement with respect to the rights of the general and limited partners participation in distributions,

the financial performance of our assets without regard to financing methods or capital structure; and 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.

Our method of computing adjusted net income per limited partner unit may not be the same method used to compute similar measures reported by other companies and may be computed differently by us in different contexts.

Three Months Ended

December 31,

Year Ended

December 31,

2006 

2005 

2006 

2005 

Net Income per Limited Partner Unit -

Basic

$0.80 

$0.80 

$3.06 

$2.89 

Diluted

$0.79 

$0.79 

$3.03 

$2.84 

Dilutive impact of theoretical distribution of earnings pursuant to EITF 03-6 -

Basic

$0.24 

$0.32 

$1.01 

$1.18 

Diluted

$0.24 

$0.32 

$1.00 

$1.15 

Adjusted Net Income Per Limited Partner Unit -

Basic

$1.04 

$1.12 

$4.07 

$4.07 

Diluted

$1.03 

$1.11 

$4.03 

$3.99 

Source: Business Wire

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